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Home My WebLink About201-031 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 10, 2013 10:00 PM To: Conrad Perry Cc: courtney.rust @cookinlet.net; David Hall; Osprey Drilling Subject: Re: GE RU -2 Sundry 313 -044 / API 50- 733 - 20501 -00 ,p773 -03( Conrad, You have approval to set retainer as proposed below per 20 MC 25.112(i). Guy Sent from my iPhone SCANNE 1 U� 0�� On Apr 10, 2013, at 4:21 PM, "Conrad Perry" <conrad.perr piDt ooki_ l t,ntft> wrote: Guy, We ran a 6 5/8" mill and 7 5/8" scraper into RU -2 and could not get past an obstruction at 12,004'. We presume it to be collapsed 7 5/8" pipe consistent with what we have found in the other wells we have worked over on the Osprey. We request approval to set a 7 5/8" cement retainer just above the obstruction at 11,950' +/- as we cannot get to the approved setting depth of 13,400'. The remainder of the procedure would stay the same, establishing an injection rate, and pump 67 bbls of 15.8 ppg cement below the retainer and dumping 3 bbls on top. We would test the retainer, 7 5/8" and 9 5/8" to 3000 psi for 30 minutes. Currently, we have just started pulling out of hole to run the 9 5/8" casing inspection /bond log, We won't be ready to pick up the cement retainer until late morning tomorrow. Best Regards, conrad VP and Drilling Manager Cook Inlet Energy, LLC 601 W. 5 Avenue STE 310 Anchorage, AK 99501 (907) 433 -3816 — Office (907) 727 -7404 - Cell _orlrad_pertyLocookinlet.net 1 • • r . „0” � jj� s THE STATE Alaska Oil Gas Conservation Commission ATM. GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 �F ALAS *P g Main: 907.279.1433 Fax: 907.276.7542 David Hall CEO 031 Cook Inlet Energy, LLC ao, 601 W. 5 Ave., Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Pool, Redoubt Unit #2 Sundry Number: 313 -044 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair `- DATED this / � day of February, 2013. Encl. SCANNED MAR 1 3 2013 • • RECEIVED STATE OF ALASKA \ •. •V „ AN 2 9 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION 0... APPLICATION FOR SUNDRY APPROVALS V AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill 0 i Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development p - 201 -031 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 601 W. 5th AVE. SUITE 310, ANCHORAGE, AK 99501 50- 733 - 20501 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 REDOUBT UNIT #2 • Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 381203, ADL 374002 REDOUBT SHOAL UNDEFINED 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 15,325' 12,607' 15,218' 12,607' 13,465' Casing Length Size MD TVD Burst Collapse Structural 200' 36" 200' 200' N/A N/A Conductor Surface 3,212' 13 3/8" 3,212' 2,918' 5,020 PSI 2,260 PSI Intermediate 9,011' 9 5/8" 9,011' 7,534' 6,870 PSI 4,760 PSI Production 5,561' 7 5/8" 14,320' 11,746' 6,890 PSI 4,790 PSI Liner 1,213' 5 1/2" 15,325' 12,601' 7,740 PSI 6,390 PSI Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • SEE ATTACHED SEE ATTACHED 3 1/2" 12.95# P -110 11,864' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): BAKER FA PACKER /WEATHERFORD HYDROW 1 PACKER 14,015'MD/9,727TVD 11,761'MD/11,511'TVD 12. Attachments: Description Summary of Proposal IS 13. Well Class after proposed work: Detailed Operations Program IS BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 2/24/2013 15. Well Status after proposed work: 1 Commencing Operations: Oil ❑ Gas El WDSPL El Suspended ® 1 ii` 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned -P- Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Courtney Rust 907 -433 -3809 Email courtneV.rustacookinlet.net Printed Name David Hall, CEO Title Signature Phone Date l✓ —e.t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: v �' `„ , Plug Integrity [0 BOP Test [i f Mechanical Integrity Test I=1 Location Clearance El / �_ Other: - 560C.3 -s'.. 13cDT �1c.s Z-�QU®gi Ah+ti,. C / `..- x 240 rw.& plu r l 4 c •-•■....{- ,f r o a-c-9 ` 2.6 A/4L Z S/ I Z C � RBDMS FEB 12 2011 Spacing Exception Required? Yes El No ['J Subsequent Form Required: `b ^ 07 APPROVED BY Approved by: � :,�bEJ�4�� COMMISSIONER THE COMMISSION Date: (- r Submit Form and b Fo 10 Revised 10/2012 Approved application is valid for 1 months from the date of approval. Attach ents in Duplicate �� d ' 0 R 1N L � .W?) 1,� • • Cook Inlet Energy_ RECEIVED JAN 2 9 2013 AOGCC January 29, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Cook Inlet Energy, LLC: Redoubt Unit #2 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry to plug Redoubt Unit #2 and pursue a sidetrack operation for Redoubt Unit #2A. Attached are completed Form 10 -403, a rig drawing, current and proposed well diagrams, and a procedure of operations. If you have any questions, please contact me at (907)- 433 -3804. Sincerely, David Hall CEO - Cook Inlet Energy 601 W. 5 Avenue, Suite 310, Anchorage, AK 99501 (907) 334 -6745 * (907) 334 -6735 fax • • RU2 Perforations MD ND 14,200- 14,542 feet 11,826- 11,926 feet 14,550- 14,612 feet 11,933- 11,984 feet 14,682- 14,788 feet 12,043- 12,132 feet 14,840- 14,942 feet 12,127- 12,171 feet 14,948- 14,980 feet 12,176- 12,263 feet 14,974- 14,996 feet 12,269- 12,296 feet 15,002- 15,020 feet 12,291- 12,310 feet 15,014- 15,130 feet 12,315- 12,331 feet 15,136- 15,152 feet 12,326- 12,427 feet 15,146- 15,192 feet 12,432- 12,482 feet 15,228- 15,256 feet 12,512- 12,556 feet • • Table of Contents Rig #35 Schematic 4 Current Completion 5 RU 2 Sidetrack Procedure 6 II • • Rig #35 Schematic oaxtw 4 ik" male PA az, xi a ,r i b 5 1 ii s1n ) ° A Illk T4 1.1) III KIX 1D4k I MIFA ' u7 fT x 30 Fl / RI 1 t 1 IA II . I', C i 1 ft- ‘ I I: l',',;N_Ir.,.. ilt 1. \` ff is 11 1 1 0 =Otkirl. lam`! ! 't . iiaia�ia� ; - ,, WO'. 4 man rift koot - �� TA I' \ I \ a \' a'rt KR r , asrr - sll� — _ trsi MI M illi -- •ii 111;;;111101 '- -'— IMO I l_ swim iisr,r - ■1# RAMS, CAP ter * */ - JIPFR:t. 5 11 Fl II t i at OSPREY i DRILLING RIG ARRANGEMENT — EAST SIDE AppoNAL mt. wAK Yk�4tl4flCL7 itsW rralsF7X4�Y�r 2 lio . OSPREY !AILING RIG mow. r 1111 ` ' V111 r..n; RIB Ik'"1 • • Current Completion Redoubt Unit 12 Completion - January 2005 — Narigam[ 1 36' 4-:4 299 TYD 154* WCldod 204 MD -6 ` 1337£' L40 291* TYD 68* ETC 3212 MD 3.102' P -114£: L -£4 t'kinq TOL X8,759 MD r 1 9508' L40 7534 TYD Sliding Slaavo4.11,707'MD l _ � 4 ?* ETC 9011MD F., Packarrot'11,761'MD .. Slidir,g 11,817' MD O 'SI!t ES F. ekxngty OM O dist1 wtrtac) jj 11 *E170.0 �'. Top ofFirk ¢+13 • LLC- 'L'OL'tr SC r. T•r Ea Mood FA Few TOL014112MD 14O15K] 7 508' L -84 11746 TYD Perforations: 29.7* Hydri1521 14324 MD 14,420' - 14,542' 14,550' - 14,612' 14,682' -14,788' 14,782' -14,834' 14,840' - 14,942' — 14,948' - 14,980' — 14,974' - 14,996' 15,002' - 15,020' 15,014' - 15,130' 4:1; 15.:16. 15,136' - 15,152' — 15,146' - 15,192 5102' L-84 12601 TVD 15,228' - 15,256' 17* Hydril521 15325 MD 33t8 "6SPF • • RU 2 Sidetrack Procedure 11/2/2012 Decompletion General Note: There is a very good chance that the pump and packer assembly are stuck in the 7 5/8" casing. Numerous examples of collapsed casing are in this field. A new abandonment procedure must be written and submitted to the AOGCC for approval if it cannot be recovered. 1. Notify AOGCC of start of operations on RU -2 and upcoming BOP test. 2. Move rig over well. Fill active pit with produced water (8.6ppg). Kill well by circulating water down the tubing, through the ESP and up the annulus. (Reservoir pressure in the Hemlock at 12,000 TVD is expected to be approximately 8.0 ppg EMW). While circulating, weight up the water in small increments with NACL, if necessary, until it is heavy enough to kill the well. a � 3. Install BPV, N/D tree, N/U BOPE. Test BOPE to_$ psi. [Note: at the discretion of the Drilling Supervisor and AOGCC Inspector (if present), blind rams will be tested after tubing is pulled from hole if there is a chance a gas bubble will settle under BPV, making it difficult or dangerous to release.] Pull BPV. 4. M/U landing joint to tubing hanger, back out lock -down screws and pull hanger to drill floor Unseating Weatherford Hydrow II Packer. (Weatherford Hydrow 11 packer at 11,761' is straight pull release)Note: tubing is 3 % ", 12.95 P -110 5. Once the tubing hanger has been pulled to the drill floor, circulate minimum of two bottoms up. 6. Ensure the well is dead and POH with the tubing (current install shows 377 joints, see attached current completion detail), checking for NORM while POH. L/D tubing and completion jewelry and send to shore. 7. Rig up wireline and run CBL (bottom 500' minimum) and Casing inspection log (to surface) in 9 5/8" casing. — 8. MU a 9 5/8" test tool, run and set it at 8,750' ( just above the top of the 7 5/8" liner). 9. Pressure test the 9 5/8" casing to 3000 psi for 30 min, record on chart. POH. 10. AOGCC must be notified 24 hours in advance of plugging the perforations. 11. M/U a cement retainer for 7 -5/8 ", 29.7# casing, RIH and set retainer at 13,400' ( above top of fish at 13,465'). Note: A waiver must be given as this is over 500' above the top perforations. 6 !c -z g 44c Z >'- izaCe)C 54..2 - :13 12. Establish injection into the perforations below the retainer, recording three rates and injection pressures. Un -sting from retainer. acts f--4 Ro 2 w 1/ , .s a t/ Cr p //6/295/.1",0 ; v 72(6 %� T (6060/. GI ✓` �' caS /* 6`, 4/&11 iNrl[ 11,4.1-11 R� t2", 7 0 Mover re' e P rtf i). Prq VICO fro 01 "' ' /?1,77) • • 13. Mix and pump 50 bbls of fres water followed by 70 • • Is of ce ent as follows: Cem - nt to consist o 342 sx Class G L Slurry Wt. 15.8 ppg .�— Slurry Yi= d 1.15 cf /sk 14. Displac cement to the singer. Sting into the retainer a d squeeze 67 bbls of ceme t below the retain r and into he perfs. Un -sting rom the retainer and pla - the last 3 bbls of c ment on t• • of the retainer. Pull p 2 stands and reverse ou /. t . 21. 31 15. P essure test cement plu , 7 -5/8" I' er and 9 -5/8" casing to 3,0b S psi for minutes. c 16. isplace production fluid with 9. ` ppg Oil based mud. P II out of e and procee with sidetrack procedure • dr' Redoubt Unit #2A. /V d k s/ Sidetrack Drilling Procedure / /e 17. M/U a 9 -5/8" bridge plug on drill pipe. RIH and set the bridge plug at 8,500'MD or depth where 9 5/8" is fully cemented for the kickoff. . Whipstock S 18. M/U the followin g 9-5/8" Trip Select Oil Tools Bottom p p stock y stem: • 9-5/8" Bottom trip anchor w/ 3-1/2" IF box • 9 -5/8" Select whipstock w/ 3 -1/2" IF pin • Starter window mill w/ 3 -1/2" Reg pin (shear screw set for 35,000 lbs.) • Full gauge upper watermelon mill w/ 3 -1/2" IF box X pin • 1 joint 4" HWDP • 4 -3/4" bumper sub • 4 -3/4" MWD survey tool w/ 3 -1/2" IF box X pin • UBHO wireline orientation sub w/ 3 -1/2" box X pin • 9 ea 4 -3/4" drill collars w/ 3 -1/2" IF box X pin • 18 ea 5" HWDP w/ 3 -1/2" IF box X pin • 5" Drill pipe to surface 19. Attach the anchor /whipstock assembly to the milling assembly via the 35k whipstock shear bolt. Then align the UBHO sub and MWD (scribe as required) with the whipstock face. This should be witnessed by the Cook Inlet Energy drilling supervisor, Olgnoonik tool hand and MWD engineer. (The UBHO orientation sub will only be used as a backup if there is an MWD failure.) 20. RIH with whipstock assembly, taking great care while running it through the BOP stack and wellhead. Run the assembly at 90 to 120 seconds per stand. Ensure the string is fully stopped when setting the rotary slips while RIH. These precautions are necessary to avoid any weakening of the whipstock shear mechanism or pre- setting of the packer. 7 • • 21. With the bottom of assembly +/ -20' above the bridge plug at +8,500', establish up and down weights, with and without circulation. Ensure sufficient stroke to tag packer and set whipstock. Do not create any sudden movements that might weaken the whipstock shear mechanism. 22. Survey the whipstock face with the MWD tool and orient the whipstock as per directional driller recommendations. Take a minimum o f three s u r v e y s, then reciprocate the assembly and verify the whipstock face has not rotated. Re- orient and survey as necessary. 23. Once orientation and depth have been verified, set down on the bridge plug with 18- 20 k Ibs to shear the slip mechanism and set the bottom trip anchor. Verify the bottom trip anchor has set by picking up a maximum of 5K Ibs over the string pick up Y� weight. . 24. Ensure +9.5 ppg mud is formulated as specified in the mud program. Install c o ditch magnets to capture milled casing cuttings. 25. With the bottom trip anchor set and the work string hanging in neutral at the L whipstock, slack off 35 k Ibs to shear the whipstock bolt. •`" t v 26. Pick up to neutral, break circulation and establish rotation at 50 -60 rpm. Lower R the milling assembly and commence milling with 2 -4k Ibs WOB and 50 -60 rpm for S- the first foot or two. Gradually increase the rpm to 100 -135 as needed and use a f £� maximum 8 -10k Ibs WOB while milling. Maintain a minimum annular velocity of 150' /min and a minimum mud yield point of 40 to ensure carrying capacity for metal A. cuttings removal. open Continue millin g until the upper watermelon mill is out in t he p en hole (after approximately 29' of milling). Condition the hole and POH. Check the OD of the upper watermelon mill. If it is more than 1/8" under gauge, a second reaming trip will be required. 4 ((. I' 8.5" Hole Section Objective: Drill 8.5" sidetrack hole and run and cement 7" production liner. Planned Depth 15,451' MD, 12,500' TVD Section Length 6,951' Planned KOP 8,500' tM Drilling Parameters: Flow Rate 450 -650 gal /m RPM 60 -160 rpm WOB 5 -35 k lb ROP 50 -200 ft/hr 8 • • Redoubt Unit #2 Proposed Abandonment - — 1 Navigator L 36" A -36 200 TVD 150 # Welded 200 MD ,• d b.. 13 3/8" L -80 2918 TVD 68 # BTC 3212 MD cl�P YS0a TOL @ 8,759 MD 1 P z 9 5/8" L -80 7534 TVD Sliding Sleeve @ 11,707' MD 47 # BTC 9011 MD [ 3 7 5/8" Cement Retainer 3 @ 13,400' , e - A'/N Fi � • Cement' /07 664 ,c3.4,01/4., r`, Top of Fish @ 13,465' (fish length = 620') r. i '" e LLC -3 Valve set in Baker Back to lop ' e'c Model FA Packer @ TOL @ 14112 MD J (( 14015 MD I 7 5/8" L -80 11746 TVD Perforations: 29.7 # Hydril 521 14320 MD 14,420' - 14,542' 14,550' - 14,612' " r ' a ' 14,682' - 14,788' _ _ 14,782' - 14,834' = —' Perforations 14,840' - 14,942' 14,948' - 14,980' ° 14,974' - 14,996' — — 15,002' - 15,020' 15,014' - 15,130' — - = EZ Drill @ 15218 MD 15,136' - 15,152' 15,146' 15,192' 5 1/2^ L -80 12601 TVD 15,228' - 15,256' 17 # Hydril 521 15325 MD 3 3/8" 6 SPF Well Name & Number: Redoubt Unit #2 Lease 1 ADL381203, ADL 374002 County or Parish: Kenai Peninsula Borough 1 State /Prov. Alaska 1 Country: 1 USA Perforations: (MD) (TVD) 1 n 1 vno -nn-, 1 nnn • Roby, David S (DOA) From: Courtney Rust <courtney.rust @cookinlet.net> Sent: Tuesday, February 05, 2013 10:48 AM To: Roby, David S (DOA) Subject: RE: Sundry application to plug Redoubt Unit #2 Well Dave, We have had a history of collapsed 7 5/8" casing on the Osprey and presume that the rapid increase in water cut was a result of that. The new pump most likely was brought on too hard pulling the 7 5/8" casing in. We will run a casing inspection log in both the 7 5/8" and 9 5/8" sections to confirm where the fault is. Additionally, there is a packer set above the pump which likely exacerbated the collapse of the casing. Water breakthrough in the Hemlock on the Osprey has traditionally been gradual. We do not expect it to be watered out. We are targeting the same area of the reservoir (twinning RU -2) in an attempt to re- establish that good rate. Thanks, Courtney From: Roby, David S (DOA) [mailto:dave.roby @ alaska.gov] Sent: Monday, February 04, 2013 6:07 PM To: courtney.rust@ cookinlet.net Subject: Sundry application to plug Redoubt Unit #2 Well Courtney, I am reviewing the reserves implications of your application to plug the RU #2 well to prepare it for drilling the RU #2A sidetrack and have a question about what happened to the well and what the purpose of this proposal is. Prior to a workover to replace the ESP in this well back in 2005 the well was producing quite well, about 800 BOPD and a water cut around 25 to 30 percent but rising steadily, but it looks like the workover operation proved to be difficult and they were unable to run the new ESP to the same depth as the old one and ended up setting it some 2000 feet shallower. When the well was brought back online oil production had plummeted and the water rate quickly shot up. Had both the water and oil rates plummeted I would suspect the reason for that would be that the new ESP couldn't be run as deep as they'd planned. However, since the water rate after the new ESP was installed was initially about the same is it was before the ESP had failed and then climbed rapidly I'm at a loss as to why the well would perform this way, and could find no other clues in our well file. I have a few questions I hope you can answer for me: 1) Do you have any explanation for why the well performed this way? 2) Do you think this behavior is related to the condition of the wellbore or indicates that the reservoir had watered out? 3) Will the proposed RU #2A be drilled to replace the existing damage RU #2 wellbore, or will it target new reserves in an un /under tapped portion of the pool? 1 • • • Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 2 + • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10 :52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art r or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F : \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 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 ] (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); IongmereCwerizon.net Subject: FW: Pacific Energy files chapter-11, it's official!!! FYI. PACIFIC ENERGY RESOURCES LTD. 111 West Ocean Blvd., Suite 1240 rR ~` "'~+~~~~~`' 1V~~i` ~- ~ ~~)~'~~ Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter 11 to Facilitate a Restructuring 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 $40 million in debtor-in-possession ("DIP")financing. The DIP facility wraps and replaces two of the Company's three asset-based credit facilities and is being provided by the lenders of the two credit facilities that are being replaced. Upon Court approval, the DIP financing combined with the Company's operating revenue will provide sufficient liquidity to fund working capital, meet ongoing obligations and ensure that normal operations continue without interruption during its restructuring. About Pacific Energy Resources Pacific Energy Resources Ltd. is an oil and gas exploration and production company based in Long Beach, California, U.S.A. Additional information relating to the Company may be found on SEDAR at www.sedar.com. The Company's web site is www.PacEnergy.com. ON BEHALF OF THE BOARD OF DIRECTORS • PACIFIC ENERGY RESOURCES LTD. Pacific Energy Resources Ltd. 310 K. Street, Suite 700 Anchorage, AK 99507 Off ce: 907-258-8600 Fax: 907-258-8601 David Hall Alaska Operations Manager Main: 907-868-2133 Cell: 907-317-8239 dmhall(?a pacenerg~.com www.pacener~,y com e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfihn _ Marker.doc -. . STATE OF ALASKA ALA À OIL AND GAS CONSERVATION COM\. bloN REPORT OF SUNDRY WELL OPERATIONS RECEIVED Repair Well U Pull Tubing 0 Operat. Shutdown D ~A!\Y 6} ~ 700S Stimulate U Orner'~ ~epair ESP Waiver D T~:$~xt~ni~ ~s Cons. Commission Re-enter Suspen~d well~h~naDe 5. Permit to Drill NUnl jer: Exploratory D 201-031 Service D 6. API Number: 50-733-20501-00 9. Well Name and Number: Redoubt Unit #2 10. Field/Pool(s): Redoubt Shoal Field 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Forest Oil Corporation Name: 3. Address: Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D 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 I ntermed iate Drilling Liner Production Liner measured 15,325 feet true vertical 12,607 feet measured 15,218 feet true vertical 12,510 feet Length Size MD 200' 36" 200' 3212' 13 3/8" 3212' 9011' 95/8" 9011' 5561' 7 5/8" 14320' 1213' 5 1/2" 15325' Plugs (measured) Junk (measured) top of fish 13,465' MD TVD 200' Burst Collapse 2~ANNED MAY 2 () 2005 7534' 11746' 1260 l' Measured depth: 14,420' -14,542',14,550'-14,612', 14,682'-14,788', 14,782'-14,834', 14,840'-14,942', 14,948'-14,980', 14,974'-14,996',15,002'-15,020', 15,014'-15,130',15,136'-15,152', 15,146'-15,192', 15,228'-15,256' (MD) 33/8",6 spf True Vertical depth: 11,826'-11,926',11,933'-11,984', 12,043'-12,132', 12,127'-12,171', 12,176'-12,263', 12,269'-12,296', 12,291'-12,310', 12,315'-12,331',12,32 12,432'-12,482',12,512'-12,556' (TVD) 3 3/8" TCP 6 spf Tubing: (size, grade, and measured depth) 3.5" 12.95 # P-11 0 Perforation depth: Packers and SSSV (type and measured depth) 14015' Baker FA 11 ,761' Weatherford Hyd. 11 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA RBDMS 8Fl MAY 2 3 2005 Treatment descriptions including volumes used and final pressure: nla 13. Prior to well operation: 656 Subsequent to operation: 5 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 161 270 1 232 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. Contact Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1649 1556 no Service D yes GINJ D WINJ D WDSPL D Sundry Number or NIA if C.O. Exempt: 305-462 Printed Name paula.,.~n."n. . . Signature ~~Pú:Z~ Title Production Engineer Phone 868-2135 ORIGINAL Date 5/19/2005 Form 10-404 Revised 04/2004 Submit Original Only Redoubt UnL ). Completion - January 2005 .. TOl @ 8,759 MD Sliding Sleeve @ 11, 70T MD Packer set @ 11,761' MD Sliding Sleeve @ 11 ,81T MD TOl @ 14112 MD Perforations: 14,420' -14,542' 14,550' -14,612' 14,682' -14,788' 14,782' -14,834' 14,840' -14,942' 14,948' -14,980' 14,974' -14,996' 15,002' -15,020' 15,014' -15,130' 15,136' -15,152' 15,146' -15,192' 15,228' -15,256' 3 3/8" 6 SPF ~~~~ ~~ 1'" ~_~I ~~ :~. ''.;, ~, : , \ ',' ·~'I' ~/ . , . ; ·1 ~ "',,', ".'" ~~~: ~~ r,'I- -41 "" .ï ~.- ...\0.... þ :.,. ·r.... .,. ':; ~~. ~ ~-~~:,: ~i: :~1::r.;L -;1 : ~ i;'.~'~. __ l't" ~' ~ .; ~ " .. " ~- .. :. '. " .~1 ,;~ ~ ~~ ~. n : ,;'i':i,:,' L[} '-' -;; ~.~ " , . "f~ .: ~36" 150# ..' " ' ~ . , "I' '"j ~t ~~ ... 13 3/8" 68# ~:{: 10. ) A-36 Welded 200 TVD 200 MD l-80 2918 TVD BTC 3212 MD t ~... '1"- ~~,":.. 3-1/2" P-110 & l-80 tubing 95/8" 47 # Centrilift ESP Assembly (top of discharge head) @ 11,864'MD l-80 7534 TVD BTC 9011 MD Top of Fish @ 13,465' (fish length = 620') llC-3 Valve set in Baker Model FA Packer @ 14015 MD 75/8" 29.7 # l-80 Hydril521 -~' ',::: Perforations - - ::- - - -- =" ..= ~ ",.- =~!- __ 1IÞ~f]Jr,_ " - ¡. '1';:;;: -: .1 ;~. EZ Drill @ 15218 MD 51/2" 17 # 11746 TVD 14320 MD l-80 Hydril 521 12601 TVD 15325 MD PEtCÝ WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/15/2005 HOURS PH 4.00 C 6.00 C DATE: 1/16/2005 HOURS PH OP 0.50 C PT 0.50 C RS 1.50 C PT 3.50 C PT 3.50 C PT 2.00 C PT 2.00 C TR 4.50 C CC 3.00 C TR 3.00 C CC DATE: 1/1712005 HOURS PH 4.50 C 1.50 C 5.00 C 0.50 C PP 5.00 C PP 1,50 C TR 0,50 C TB 0,50 C TR 1.50 C TB 0,50 C RS 3.00 C TB DATE: 1/18/2005 ) ) Today's Date: 3/22/2005 OPERATIONS SUMMARY REPORT REDOUBT UNIT #2 #5 REDOUBT SHOAL 2 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045528 507332050100 50-733-20501-00 MOBE RIG, RU SAME; THEN PULL DSS: o 12,300.00 MUD WT: CUM COST TO DATE: DEPTH: OP BP BP ACT ACTIVITY DESCRIPTION BLEED PRESSURE FI WELL AND LINES. SET BPV. REMOVE BOLTS FROM TREE AND WELL HEAD. FINISH NID TREE. NIU RISER, BOP'S AND FLOW LINES, CHOKE AND KILL LINES. PULL BPV AND INSTALL TWO WAY CHECK. NOTE: LEFT VOICE MAIL WI AOGCC AND SENT EMAIL TO THREE DIFFERENT ADDRESSES INFORMING THEM OF UPCOMING BOP TEST. NO REPONSE AS OF YET. DSS: o 56,300.00 MUD WT: CUM COST TO DATE: DEPTH: ACT ACTIVITY DESCRIPTION PULL BPV AND INSTALL TWO WAY CHECK. LOWER MOUSE HOLE THROUGH RIG FLOOR TO GET MEASUREMENT FOR PROD DECK MOD. MIU TEST JOINT AND XO'S TO TEST BOP'S. TEST TOP RAMS, INSIDE KILL, OUTSIDE KILL, MANUAL CHOKE, HCR TO 250 PSI LOW TO 3500 PSI HI FOR 5 MINS = OK. TEST CHOKE MANIFOLD VALVES, FLOOR VALVES, TOP DRIVE VALVES, HYDRIL BTM RAMS, BLIND RAMS TO 250 PSI LOW TO 3500 PSI HI = OK. PERFORM KOOMEY TEST. PULL TWO WAY CHECK. INSTALL LANDING JNT AND BACK OUT LOCK DOWNS. ATTEMPT TO PULL HANGER, PULL WI 235K WI 4' STRETCH. FILL ANNULAS WI 141 BBLS. LOSSES @ 2 BPH, BREAK CIRC W/19 SPM @ 1050 PSI. CIRC AND COND MUD, MONITOR LOSSES @ 0 BHP, WORK PIPE, PULL 235K, BREAK CIRC W/19 SPM @ 1050 PSI, 20 SPM @ 975 PSI, 23 SPM @ 1650 PSI, AND 20 SPM @ 1170 PSI. WORK PIPE EVERY 15 MINS. UP wr 235K DOWN wr 170K. BREAK CIRC EVERY HOUR @ 00:30- 20 SPM @ 1173 PSI, @ 01 :30- 21 SPM @ 1235 PSI, @ 02:30- 20 SPM @ 1150 PSI. CRIC BTMS UP @ 2 BPM = 2354 PSI. DSS: o 103,800.00 MUD WT: DEPTH: CUM COST TO DATE: OP ACT ACTIVITY DESCRIPTION CC CONT CIRC @ 2 BPM WI 28 SPM @ 2150 PSI, NO LOSSES OR GAINS TO WELL BORE. PP SHUT PUMPS OFF AND MONITOR WELL, NO FLOW. RlU TO RUN WIRELlNE. PP MAKE 2.65 GUAGE RING RUN TO 13,514'. DECISION WAS MADE TO CUT PIPE @ + OR -13,450' DUE TO THE FACT THAT WE CANNOT ROTATE PIPE BECAUSE OF CABLE, MAKE UP TORQUE FOR 8 RD PIPE AND ONLY 4' TO WORK PIPE DUE TO HANGER STILL BEING IN HOLE AND MAX PULL ON 8 RD. PULL 220K +, SET PIPE IN SLIPS, MIU CHEMICAL CUTTER AND CCL. RIH, CUT PIPE @ 13,440' 5' BELOW COLLAR @ 13,335'. POOH RID APRS. PULL HANGER TI FLOOR, 158K UP WT. BLEED GAS FI CONTROL LINES. RlU TEST PUMP. PUMP DOWN CONTROL LINES @ 4500 PSI = NO GO. PUMP DOWN INJECTION LINES = NO GO. UD LANDING JT. UD TUBING AND HANG OFF SHEAVE IN DERRICK. SERVICE RIG. UD 3 1/2 TUBING AND CENTRILlFT ELECTRIC LINE. DSS: DEPTH: o 145,900.00 MUD WT: CUM COST TO DATE: Page 1 of 7 PERCy' WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/18/2005 HOURS PH OP 0.50 C TR 1.00 C TR 8.00 C TR 1,50 C TR 9.50 C TR 1.00 C TR 2.50 C TR DATE: 1/19/2005 HOURS PH OP 5.00 C TR 1.00 C RS 1.00 C TR 5.50 C TR 0.50 C TR 11.00 C TR DATE: 1/20/2005 HOURS PH OP 2.50 C TR 0.50 C CC 2.50 C TR 1.50 C FI 0.50 C FI 1.00 C FI 0.50 C FI 1.00 C FI 0.50 C FI 2.50 C FI 2.00 C FI 1.00 C FI 2.00 C FI 4,00 C FI 2.00 C FI DATE: 1/21/2005 ) ) Today's Date: 3/22/2005 OPERATIONS SUMMARY REPORT REDOUBT UNIT #2 #5 REDOUBT SHOAL 2 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045528 507332050100 50-733-20501-00 MOBE RIG, RU SAME; THEN PULL DSS: o DEPTH: MUD WT: CUM COST TO DATE: 145,900.00 ACT ACTIVITY DESCRIPTION UD 31/2 TUBING F/12,200' TO 11,600'. CUT SPLICE IN ESP WIRE. POOH UD 3 1/2 TUBING AND CENTRIUFT CABLE F/11 ,600' TO 9,200' CHANGE OUT ESP CABLE SPOOL. POOH UD 3 1/2 TUBING AND CENTRIUFT CABLE F/9200' TO 4000'. SPLICE ESP CABLE AND WIRE. CONT POOH UD TUBING AND CENTRILlFT CABLE F/4000' TO 2,600'. DSS: MUD WT: DEPTH: o CUM COST TO DATE: 211,300.00 ACT ACTIVITY DESCRIPTION FINISH POOH AND UD 3 1/2 TUBING AND CENTRILlFT CABLE, RECOVERED 429 JNTS OF TBG AND 205 CLAMPS. TOP OF FISH @ 13,440'. CLEAN RIG FLOOR. INSTALL WEAR RING AND UD HANDLING TOOLS. PIU 5 3/4 CUT LIP GUIDE, HOLLOW MILL OVERSHOT, BUMPER AND OIL JARS, 12 4 3/4 DRILL COLLARS, ACCEL JAR AND 30 JNTS OF 3 1/2 DP. RIU WEATHERFORD TONGS. PIU AND RIH WI 3 1/2 TUBING TO 9500'. DSS: o 289,200.00 MUD WT: DEPTH: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION TIH TO 11,300'. FILL PIPE AND NOTE CIRC, TORQUE AND PRESSURE. FINISH TIH TO 13,280'. WASH AND REAM F/13,280 TO 13,349' (DPM). TAG FISH. DRESS FISH AND LATCH SAME, 30 RPM I 5-6K TORQUE /4 BPM I 550 PSI. WORK PIPE AND JARRING @ 260K I 2 BPM I 950 PSI, MAKE 2-4" WHEN JARS HIT. CLOSE BAG BULLHEAD 5 BBL /1150 PSI, BLED OFF 50 PSI IN 5 MINS CAN'T PUMP IN. JARRING @ 260K/2 BPM 1950 PSI, MAKE 1-2" EACH TIME JARS HIT. CLOSE BAG BULLHEAD T/1000 PSI 14.2 BBL, NO BLEED OFF IN 5 MINS. JARRING @ 260K 12 BPM I 950 PSI. UO SINGLE AFTER 15', JARRING @ 260K 12 BPM 1950 PSI. LOST POWER FI SHORE TO RIG. JARRING @ 260K /2 BPM I 950 PSI. JARRING FISH, MOVED FISH @ 04:00 HRS 26.5' UP HOLE. NEW TOP OF FISH @ 13,412'. JARRING ON FISH @ 05:45 JARS HIT AND WE MADE 20 FT, NOW MAKING l' EACH TIME JAR HITS. DSS: o 381,200.00 DEPTH: MUD WT: CUM COST TO DATE: Page 2 of 7 PERe¥' WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/21/2005 HOURS PH OP 11.00 C FI 13.00 C FI DATE: 1/22/2005 HOURS PH OP 0.50 C FI 1.00 C FI 2.50 C RS 2.00 C FI 2.00 C FI 1.00 C FI 6.50 C FI 1.00 C FI 1.50 C FI 6.00 C FI DATE: 1/23/2005 ) ) Today's Date: 3/22/2005 OPERATIONS SUMMARY REPORT REDOUBT UNIT #2 #5 REDOUBT SHOAL 2 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045528 507332050100 50-733-20501-00 MOBE RIG, RU SAME; THEN PULL DSS: DEPTH: o 381,200.00 MUD WT: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION JARRING ON FISH F/13,412' TO 13,351' WI 270K UP AND 120K DWN, CLOSE HYDRIL EVERY HR AND PRESSURE UP ON TBG AND ANNULAS TO 1000 PSI. FROM 14:30 TO 17:00 ONLY MAKE 1'. WHILE JARRING AND CIRC ON FISH LOST 0 FLUID TO FORMATION. WITH 50' JARRING OUT OF HOLE, FISH WOULD GO DOWN HOLE WITH COMPLETE STRING ON FISH. TOTAL FOOTAGE JARRED OUT WAS 89'. ATTEMPT TO RELEASE FROM FISH, WORK RIGHT HAND TORQUE DOWN, COULD ONLY GET 10 ROUND OF TORQUE WORKED IN TBG WI 7000 TORQUE. PUMPED AND SPOT TWO DRUMS OF MI LUBTEC AT TOP OF FISH WORKED 17 ROUND OF TORQUE DOWN TBG WI 7500 TORQUE, WORKING RIGHT HAND TORQUE WI PUMP ON AND OFF. ATTEMPT TO UNLATCH GRAPPLE FI FISH @ 13,355', UP WT 170K OWN WT 110K MAINTAIN 7000 FT LBS OF TORQUE ON STRING PUMPING 2 BPM @ 500 PSI. DSS: DEPTH: o 428,700.00 MUD WT: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION CLOSE ANNULAS AND PRESSURE UP TO 1000 PSI AND HOLD FOR 30 MINS. WORK TORQUE OUT OF DOWN HOLE PIPE. CLOSE ANNULAS AN PRESSURE UP TO 1000 PSI AND HOLD FOR 30 MINS. SLIP AND CUT DRILL LINE AND SERVICE RIG. INSPECT DERRICK. JARRING, UP WT 270K DOWN 110K 6' PULLED @ 13,341', JARRED FISH UP HOLE 10' TO 13,351'. JARRING ON FISH @ 13,351'. ATTEMPT TO WORK FISH DOWN HOLE. POUND DOWN WI BUMPERSUB, CLOSE ANNULAS AND OPEN KILL LINE, PRESSURE UP TO 1000 PSI AND HOLD. BOAT ARRIVED AT 17:30 HRS WI APRS UNIT BUT NO HANDS WI FUTHER INVESTGATION IT WAS DISCOVERD THAT THE PEOPLE ON PLATFORM C DID NOT WAKE UP HANDS TO GET ON BOAT, WHEN WE ASKED BOAT TO RETURN TO PLATFORM WE WERE TOLD TO CALL XTO FOR PERMISSION, XTO DISPATCHER TOLD US THAT PERSONAL SHOULD NOT BE TRANSPORTED BY BOAT UNLESS IT WAS A LAST RESORT, THEN BOAT CAPTAIN PROCEEDED TO CALL COAST GUARD IN REGARDS TO TRANSPORTING PEOPLE AND WAS TOLD THAT THEY COULD NOT. SCOTT WI XTO CALLED AND SAID HE WOULD CHECK INTO WHY THE BOAT CAPTAIN DID THIS. ATTEMPED TO LINE UP NITE FLIGHT TO BRING HANDS TO RIG = NO GO. BLEED OFF AND JAR OWN WI BUMPER SUB F/13,351' TO 13,459', PUT 8 ROUNDS INTO PIPE AS PER COMPANY REP. BROKE LOOSE AND PUSHED DOWN T/13,347' F/13,439'. WORK REAM PUMPING 2 BPM. PULL F/13,439' T/13,410' TIGHT. WIPE AND REAM. ATTEMPT TO WORK FISH UPHOLE JARRING AND ROTATING, UP WT 260K WHEN JARRING MAX TO 7000 FT/LBS. FISH DEPTH @ APPROX 13,425' CIRC @ 2 BPM WI 500 PSI. DSS: DEPTH: 472,600.00 o MUD WT: CUM COST TO DATE: -.t Page 3 of 7 PERCy. WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/2312005 HOURS PH OP 0.50 C FI 3.00 C FI 1.00 C FI 1,50 C FI 1.50 C FI 0.50 C FI 2.50 C CC 4.00 C FI 2.00 C FI 1.50 C FI 4.00 C FI 2.00 C FI DATE: 1/24/2005 HOURS PH OP 1.00 C FI 0.50 C TR 0.50 C RS 15.50 C TR 0.50 C 6.00 C DATE: 1/25/2005 ) ) Today's Date: 3/22/2005 OPERATIONS SUMMARY REPORT REDOUBT UNIT #2 #5 REDOUBT SHOAL 2 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045528 507332050100 50-733-20501-00 MOBE RIG, RU SAME; THEN PULL DSS: o 472,600.00 MUD WT: DEPTH: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION CLOSE ANNULUS PRESSURE UP TO 1000 PSI AND HOLD FOR 30 MINS. CONT ATTEMPTING TO WORK FISH UP HOLE, JARRING @ 260K UP WT AND ROT UP WT OF 200K AND 7K TORQUE. TOP OF FISH @ 13,425'. HELD SAFETY MEETING WI CREW DISCUSSING STATION BILL ASSIGNMENTS IN THE EVENT OF AN EMERENCY SUCH AS FIRE OR ABANDON PLATFORM. WHILE WAITING ON APRC HAND TO ARRIVE ON RIG. RlU WIRE LINE TO RUN THROUGH TOP DRIVE WI CCL. PIU STRING SHOT AND CCL. RlU APRC WIRE LINE, HELD PRE JOB SAFETY MEETING, PIU SHOT AND LOCATER MIU PAC OFF. RIH TO 300' AND CHECK TOOLS, LOCATER NOT WORKING POOH.( BOTTOM SHEAVE JUMPED SLIGHTLY, OBVIOUSLY FROM DISCHARGE OF STRING SHOT.) APPROX 6" STUB BELOW CONNECTION AND STRING SHOT LEFT IN HOLE. RlU AND REVERSE OUT, MIX 25 BBL HI VIS PILL. TRANSFER PILL INTO SUCTION LINE WHILE WAITING ON POLLARD WIRE LINE. RlU POLLARD WIRE LINE AND PIU TOOLS WI 1.91 OVERSHOT. RIH WI WIRE LINE TAG @ 13,004', POOH, NO FISH. CHANGE TO IMPRESSION BLOCK, RIH AND TAG @ 13,523 (WLD) POOH AND UD POLLARD TOOS AND RID WIRE LINE. RID REVERSING PUPS, FLOOR VALVE AND XO'S. WORK IN RIGHT HAND TORQUE 7500 LBS ADJUSTING TOP DRIVE TORQUE. RlU AND RIH WI APRC WIRElINE WI STRING SHOT AND CCL TO 13,410', WORKING LEFTHAND TORQUE AND SHOOT @ 04:00 HRS. POOH WI WIRELlNE AND RID. POOH WI TBG. NOTE: MRJOHN CRISP WI AOGCC WAVIED WITNESSING BOP TEST ON 1-22-05 @ 10:30 AM. NOTE: MR JOHN CRISP WI AOGCC GAVE 24 HR BOP EXTENSION ON 1-22-05 @ 20:30 HRS. DSS: o MUD WT: DEPTH: CUM COST TO DATE: 518,300.00 TR PT ACT ACTIVITY DESCRIPTION POOH WI WIRELlNE UD TOOLS AND RID SAME. POOH W/3 1/2 TBG AND FISH F/13,400' TO 13,250'. LUBRICATE RIG AND ADJUST TOP DRIVE SERVICE LOOP. FINISH POOH WI 3 1/2 TBG AND FISH. UD BHA AND 25' OF FISH. NEW TOP OF FISH @ 13,465' + OR -. RID WEATHERFORD TONGS AND CLEAN UP RIG FLOOR HOLD WEEKLY FIRE DRILL, CHECK FIVE NEW FIRE ALARM STATIONS TO MAKE SURE ALL WORKING. STATIONS LOCATED ON RIG FLOOR, MOTOR ROOM, PUMP ROOM, UNDER NORTH AND SOUTH CRANES ON PIPE DECK. PIU TEST JOINT, PULL WEAR BUSHING. TEST BOPS. NOTE: @ 08:00 AM ON 1-23-05 WE NOTIFEID NORTH SLOPE INSPECTOR WI AOGCC THAT WE WOULD BE TESTING BOP'S TODAY. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 572,400.00 Page 4 of 7 PEtC'" WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/25/2005 HOURS PH OP 1.00 C RS 5.00 C TR 1.50 C TR 3.00 C TR 2.00 C TR 7.50 C TR 0.50 C TR 3.50 C TR DATE: 1/26/2005 HOURS PH OP 0.50 C CC 3.50 C TR 2.00 C CC 3.00 C TR 2.00 C TR 5.00 C TR 4.50 C TR 3.50 C TR DATE: 1/27/2005 HOURS f!! OP 2.00 C TR 4.00 C TR 4.00 C TR 2.00 IS~C WO 7.00 C TR 5.00 C CC DATE: 1/28/2005 ) ) Today's Date: 3/22/2005 OPERATIONS SUMMARY REPORT REDOUBT UNIT #2 #5 REDOUBT SHOAL 2 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045528 507332050100 50-733-20501-00 MOBE RIG, RU SAME; THEN PULL DSS: o 572,400.00 DEPTH: MUD WT: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION HOLD PREJOB SAFETY MEETING WI ALL RIG CREW AND SERVICE PERSONAL ON PICKING UP AND RUNNING ESP PUMP ASSY. P/U BAKER ESP PUMP ASSY AND BEGIN MAKING UP SAME. P/U CONTROL LINE SHEAVE AND RUN CABLE THRU, HANG SHEAVE, FILL PUMP WI OIL. CONNECT CONTROL LINE TO PUMP. P/U PIECE #4 AND #5 OF MOTOR AND PUMP ASSY. CLEANNING TRIP TANK AND PIT #6. BAND CABLE. RlU WEATHERFORD. P/U JT OF 3112 TBG, SLEEVE, JNT OF 3112 TBG, 7518 HYDRO' II PACKER ASSY AND BAND CABLE. MAKE SPLICE FI MOTOR ASSY, WORK ON CLEANING PITS, CLEAN RIG FLOOR AND CELLAR. PLUG CABLE INTO PACKER AND TEST SIGNAL = OK. M/U RIV SLEEVE AND PUP JNTS, RIH W/3 1/2 12.95# P-110 WTS-6 PROD TBG, RABBIT EACH STAND GOING INTO HOLE. DEPTH @ 06:00 IS 1900'. DSS: DEPTH: o MUD WT: CUM COST TO DATE: 624,100.00 ACT ACTIVITY DESCRIPTION KIU AND BREAK CIRC, MAX CIRC PRESSURE 500 PSI W/10 SPM @ 2150'. CONTINUITY TEST ON ESP CABLE. TIH W/3 1/2 TBG F/2000' TO 4000', HIT TIGHT SPOT @ 2550', 10K OVER DOWN WT AND 3K OVER UP WT. BREAK CIRC WI MAX PRESSURE 500 PSI W/10 SPM @ 3950'. SPICE ESP CABLE. MAG CABLE OK.' MAKE SPLICE TO CABLE @ 3950', UP WT 50K, BLOW DOWN TOP DRIVE. TIH F/4000' TO 6000'. PUMP TRIP TANK, MAG CABLE OK. BREAK CIRC W/4 BPM @ 200 PSI. TIH F/6000' TO 7300'. MAKE SPLICE. MAG CABLE OK. RIU TO P/U 31/2 TBG AND BUILD STDS. BUILD 25 STDS WHILE WAITING FOR SPLICE. UNLOAD 2 7/8 TBG FI BOAT. TIH WI TBG F/7300' TO 8000'. STARTED PUMPING CORROSION INHIBITOR DOWN TBG, FILL PIPE AND BREAK CIRC MAX PRESSURE 500 PSI @ 10 SPM, 5 BBL CORROSION INHIBITOR PUMPED. CONT TIH W/3 1/2 TBG F/8000' TO 10,100'. DSS: o 1,148,300.00 DEPTH: MUD WT: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION CON'T RIH wI 3-1/2" TBG & ESP CABLE TO 11,163' DPM. RABBIT EACH STD. BREAK CIRC & PUMP 5 bbl @ 10 spm 1500 psi. MAKE CABLE SPLICE, MEG & CHK CONTINUITY-OK. RIH TO 11,920' DPM; TOOK 10k WT & FELL THRU. CON'T RIH TO 12,009' DPM & TOOK 20k WT; PU TO 158k (20k OVER) & WOULD NOT PULL FREE. MEG CABLE & CHK CONTINUITY-OK. RU & CIRC w/7 spm @ 380 psi. PULL 165k (27k OVER) & PIPE CAME FREE. LD (3) JTS & CHECK wI DENVER OFFICE. CLEAR RIG FLOOR & RIG SERVICE WHILE WAIT ON ORDERS FROM DENVER. INFORMED BY DENVER OFFICE TO PROCEED WITH SETTING PKR ABOVE TITE SPOT @ 12,009' DPM. CALCULATE SPACEOUT & ADD PUP JTS (1) FULL JT BELOW HANGER ASSEMBLY. CHECK CABLE CONTINUITY PRIOR TO INSTALL HANGER. MU HANGER ASS'Y & LNDG JT. INSTALL PENETRATOR IN HANGER & SECURE SAME. CUT CABLE & CONNECT TO PENETRA TOR; MEG & CHECK CABLE-OK. RIH & LAND HANGER w/30k; CHK PINS TO BE SURE HANGER IN POSITION-OK. PU HANGER 54" FOR +1- 30k SETDOWN WT ON PKR. (BOTTOM OF PUMP ASS'Y-11 ,993' DPM; TOP OF PKR- 11 ,761' DPM)~ RU & CIRC M-I 'CONQOR 404' INHIBITOR FOR PKR FLUID w/1 0 spm @ 580 psi. DSS: o 1,195,200.00 MUD WT: DEPTH: CUM COST TO DATE: Page 5 of 7 PIIC" WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 1/28/2005 HOURS PH OP 9.50 C CC 3.50 C Sl 11.00 IS-C WO DATE: 1/29/2005 HOURS PH OP 2.00 IS-C WO 2.00 IS-C WO 6.00 C SL 2.00 C 3.50 C 1,50 C 1.50 C PT 5.50 C BP DATE: 1/30/2005 HOURS PH OP 3.00 C WH DATE: 2/25/2005 HOURS PH 24,00 C DATE: 2/26/2005 ) ) Today's Date: 3/22/2005 OPERATIONS SUMMARY REPORT REDOUBT UNIT #2 #5 REDOUBT SHOAL 2 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045528 507332050100 50-733-20501-00 MOBE RIG, RU SAME; THEN PULL DSS: DEPTH: o 1,195,200.00 CUM COST TO DATE: MUD WT: ACT ACTIVITY DESCRIPTION CON'T CIRC & DISPLACE ANNULUS WITH 8.5# FSW & M-I'CONQOR 404' PKR FLUID. RU POLLARD SIL UNIT & LUBR MU 2.52" GR, 1-1/2" STEM. SPANG JARS & OIL JARS (24' L). RIH wI GR & TAG @ 11,729' WLM (TOP RIV SLEEVE @ 11,709' DPM). PU CLEAN, NOT STICKY. RIH & TAG SAME PLACE; PU -OK. POH & CHECK GR SIZE-OK. BOTTOM OF TOOL HAD SHINY BEVEL APPROX 3/4 AROUND OD. MU 2.30" GR & RIH. TAG TITE SPOT @ 11.730' WLM. JAR DOWN TWICE & FELL THRU; PU & DRAG THRU SAME TITE SPOT @ 11,730' WLM (DID NOT HAVE TO JAR THRU COMING UP). RIH & SETDOWN @ 11,730 WLM; JAR TWICE & FELL THRU. CON'T RIH & TAG @ 11,838' WLM (TOP OF PUMP ASS'Y @ 11,863' DPM). POH wI GR; PULL THRU SAME TITE SPOT @ 11-,730' WLM. CHECK wI BAKER ON ID OF PRESSURE HEAD (3.00"). 3-1/2", 9.3# TBG (2.992"). WAIT ON 2.125" OD INFLATABLE BRIDGE PLUG (IBP) & E-LlNE UNIT. DSS: DEPTH: o 1,277.600.00 MUD WT: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION WAIT ON 2.125" (IBP). ORDERS FROM DENVER TO CANCEL TOOLS & ORDER SLlCKLlNE TOOLS. WAIT ON POLLARD SLlCKLlNE TOOLS (SWAGES, BROACH & IMPR BLOCK). MU 2.562" 'PR' PLUG BODY WITHOUT PACKING TO LOCATE NIPPLE. RIH & TAG TITE SPOT @ 11,729' WLM; POH. DRESS PLUG BODY wI PACKING & RIH IN SELECTIVE POSITION.· TAG 'RIV SLEEVE @ 11,729' WLM. WORK PLUG THRU NIPPLE & RIH. TAG LOWER 'RIV' SLEEVE @ 11,838' WLM. SET PLUG BODY IN NIPPLE @ 11,838' WLM & POH. MU PRONG ON PULLING TOOL; TEST LUBR TO 3500 psi. RIH; SET PRONG IN PLUG BODY @ 11,838' WLM. PT PRESSURE UP TBG TO 3500 psi MAX & SET WEATHERFORD 7-5/8" HYDROW II PKR @ 11,761' DPM. POH wI PRONG. CLOSE HYDRIL & ATTEMPT TO TEST PKR; HAVE TBG COMMUNICATION THRU INJECTION LINES IN HANGER; UNABLE TO TEST. SL RIH wI PULLING TOOL & PULL PLUG BODY @ 11.838' WLM. POH & RD SIL EQUIP. WH LAND TBG HANGER wI 30k SETDOWN WT ON PKR SET LOCK DOWN PINS & SECURE SAME. (NOTE: PKR SET @ 11,761'; RIV SLEEVE @ 11,709' & 11,817'; EOA @ 11,993') RAN TOTAL 377 JTS. 3-1/2",12.95#, P-110, BTS-6 TBG. RU ON CSG & TEST PKR wI 500 psi-OK. BACKOUT LANDING JT & lD SAME. INSTALL BPV IN TBG HANGER & PREP TO ND. ND BOPE & RISER SPOOL. NIU TREE AND TEST. DSS: DEPTH: o 1,598,300.00 MUD WT: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION NID BOP'S, NIU TREE AND TEST VOID TO 5000 psi-OK. PULL BPV & INSTALL 2-WAY CHECK. TEST TREE TO 3500 psi-OK. PULL TWO WAY CHECK, SECURE WELL & PREP TO SKID RIG. SKID RIG TO RU #6 @ 1000 HRS; TURN WEll OVER TO PRODUCTION.- FINAL REPORT DSS: DEPTH: o 1,612,600.00 MUD WT: CUM COST TO DATE: OP ACT ACTIVITY DESCRIPTION MO SCOPE DOWN DERRICK, LD TOP DRIVE & SECURE IN CRADLE. DISCONNECT HYDRAULIC HOSES & ELEC LINES & REMOVE FROM CRIBBING. REMOVE ROOF CAPS & LD WIND WALLS. UNSTRING BLOCKS & LD SAME. CON'T TO RIG DOWN & PACKAGE RIG FOR DE-MOB. BACKLOAD BOPE & MISC RENTAL EQUIP. BACKLOAD PORTION OF RIG FOR lOAD #1 & DE-MOB TO SHORE. DSS: o 1,628,400.00 MUD WT: DEPTH: CUM COST TO DATE: Page 6 of 7 PERC,! WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: DATE: 2/26/2005 HOURS PH OP 24.00 C MO DATE: 2/27/2005 HOURS PH OP 24.00 C MO DATE: 2/28/2005 HOURS PH OP 24.00 C MO DATE: 3/1/2005 HOURS PH OP 24.00 C MO DATE: 3/2/2005 HOURS PH OP 24.00 C MO ) )' Today's Date: 3/22/2005 OPERATIONS SUMMARY REPORT REDOUBT UNIT #2 #5 REDOUBT SHOAL 2 AFE NO: WELL ID NO.: API NO.: EVENT DESC.: 045528 507332050100 50-733-20501-00 MOBE RIG, RU SAME; THEN PULL DSS: o 1,628,400.00 CUM COST TO DATE: MUD WT: DEPTH: ACT ACTIVITY DESCRIPTION CON'T RD RIG; BACKLOAD RIG PACKAGES,ON TO MN 'CHAMPION' FOR LOAD #2 (PARTIAL LOAD DUE TO EQUIP ON BOAT FOR 'XTO' PL T). CON'T RIGGING DOWN. LOWER SUB-STRUCTURE & LD DERRICK. BACKLOAD RIG PACKAGES ON WORKBOAT FOR LOAD #3 & TRANSPORT TO SHORE. DSS: o 1,642,000.00 MUD WT: CUM COST TO DATE: DEPTH: ACT ACTIVITY DESCRIPTION REMOVED FLOOR. REMOVE CHOKE & KOOMEY BUILDINGS & LANDINGS. REMOVE JACKING RAMS. CLEAN WHITE IRON. READY FOR BACKLOAD. PULLED CELLAR BOXES & CLEANED. BACKLOAD WORKBOAT LOAD #4 (PARTIAL LOAD, CAPTAIN COULD NOT GET CLOSE ENOUGH TO RIG TO LOAD STERN). PULLED BOLTS IN WHITE IRON. CLEAN PULL WIRES. LOADED 40' FLAT WITH CELLAR BOXES & LANDING. PULLED CELLAR & CLEAN. PULLED WHITE IRON CELLAR WINGS. CLEAN & STACK FOR BOAT. ORGANIZED HOSES FI BASKET INTO 4 X 4 BOXES. STACKED 4 X 125 ON WHITE IRON. PULLED 1 SKID BASE WHITE IRON & CLEANED. READY 2ND PIECE FI REMOVAL & PRE-RIG. NEXT BOAT TO ARRIVE APPROX. 08:00 HRS FOR NEXT BACKLOAD. DSS: o 1,674,500.00 MUD WT: CUM COST TO DATE: DEPTH: ACT ACTIVITY DESCRIPTION CON'T RD & CLEAN RIG FOR TRANSPORT TO SHORE. BACKLOAD WORKBOAT LOAD #5 (DERRICK MAST, LOWER RIG FLOOR, GEN HOUSE #1 & #2, HYDR POWER UNIT, SPACER BUILDING & MISC BUNDLES) & TRANSPORT TO SHORE. DISMANTLE WHITE IRON BASE & CLEAN FOR TRANSPORT. CUT AWAY MAT FROM WHITE IRON. SECURED LOADS ON FLAT. CUT AWAY HAND RAILS FROM WHITE IRON. LOADED JACKS ON 20' FLAT. STACK & SECURED WHITE IRON FOR BOAT. LOADED BOAT #6 WITH 3-PIECES OF WHITE IRON, MAT WITH HP HOSES, MCC PARTS HOUSE & SMOKE SHACK. DSS: DEPTH: o 1,819,300.00 MUD WT: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION CONTINUED DEMOB RIG: CLEAN EQUIPMENT AND DECK. LOAD BOAT #7, ALL WHITE IRON. CONTINUED CLEANING DECK AND REMAINING EQUIPMENT. LOAD BOAT #8. ALL MATTING BOARDS AND MISC. CLEAN DECK AND WAITING FOR FINAL BOAT TO ARRIVE TO COMPLETE DEMOB. DSS: DEPTH: o 1,856,600.00 MUD WT: CUM COST TO DATE: ACT ACTIVITY DESCRIPTION FINISH CLEANING DECK & SERVICE CRANES. BACKLOAD WORKBOAT LOAD #9 wI ALL MISC ITEMS, TRASH, SCRAP IRON, LOOSE BOARDS & CONTAINERS. TOP-OFF wI FUEL & WATER FOR PL T. INSPECT TOP DECK AREA WITH TOOLPUSHER & PROD OPER- OK. (NOTE: PROD WILL HAVE WELDING CREW PATCH REMAINING HOLES IN DECK LATER THIS WEEK WHILE WORKING ON INJ MANIFOLD). LAST RIG CREW DEPART @ 1700 hr5. RD EPOCH HARDWARE & SHIP TO SHORE BASE. RELEASE MN 'CHAMPION' 3/1/05 (E-MAIL TO VENDOR FROM CHUCK WILSON). FINAL REPORT Page 7 of 7 ) AI/ASKA. OIL AM) GAS CONSERVATION COMMISSION Paula Inman Production Engineer Forest Oil Corporation 310 K. Street, Ste 700 Anchorage, AK 99501 Re: Redoubt Unit #2 Sundry Number: 304-462 Dear Ms. Inman: ) ;;'t}f~>() 31 FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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 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 thia day of December, 2004 Encl. SCANNEDDEC 142004 @ FOREST 0 I L ) CORPORATION 310 dYCQ%~PÆ{. 99:uëe 700 Q9I~IuM~J QWk/,ý1ca .9.9501 (907) 258-86'00 . (907) 258-86'0:1 (c;fþa.;¡;) November 19,2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Forest Oil Redoubt Unit #2 ESP Repair Dear Mr. Norman, The Electric Submersible Pump (ESP) in the Redoubt Unit #2 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, ~L~, Paula Inman Production Engineer Forest Oil Corporation Attachments ...--..., , \ I ) i..-) ~r"¡f\lj\L 1011\Jli Abandon U Alter casing D Change approved program D 2. Operator Name: Forest Oil Corporation 3. Address: \. ~ '. 1. Type of Request: ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROYAL 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): 8. Property Designation: ~ ;). 0 2004 Perforate U Waiver U Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 0 D Annular Dispos. U Other 0 Repair ESP Exploratory D Service D 6. API Number: 50-733-20501-00 90' MSL 9. Well Name and Number: Redoubt Unit #2 Total Depth TVD (ft): 12,607' Length 200' 15,218' Size MD 200' 10. Field/Pools(s): 11. Total Depth MD (ft): ADL-381203 (Suñace), ADL-374002 (TD) PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 15,325' Casing Structural Conductor Surface Intermediate Drilling Liner Production Liner Perforation Depth MD (ft): 14,420' - 15,256' Packers and SSSV Type: 36" 3,212' 13-3/8" 9,011' 9-5/8" 5,561' 7 -5/8" 1,213' 5-1/2" Perforation Depth TVD (ft): 3,212' 9,011' 14,320' 15,325' Tubing Size: 201-031 Redoubt Shoal Oil Field 12,510' Plugs (measured): TVD 200' 2,918' 7,534' 11,746' 12,601' Tubing Grade: 11,826' - 12,556' Baker FA packer wI LLC-3 valve 3-1/2" Packers and SSSV MD (ft): P-110 14,015' MD 13,803' 12. Attachments: Description Summary of Proposal L::J Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: BP @ 15,218' Burst Junk (measured): None Collapse N/A N/A 5,020 2,260 6,330 4,750 6,890 4,790 7,740 6,280 Tubing MD (ft): 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D 12/7/2004 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name pa..la Inman Title Signature4~{~ ~.Phone Date: 868-2135 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness BOP Test ~ 0 Service D D Abandoned D D WDSPL D Plugged WINJ Contact Paula Inman Production Engineer, Forest Oil Date /1/0r Sundry Number: 3D t-\ - -'i ~ :) Mechanical Integrity Test D Location Clearance D Other. ~~~, ~\"'\.""'''h-", \<,.0 ~ \~<¡,;\, ~ t? ~S~'''~~\ "=:. '\ ¿,a.. 'í~ , RBDMS BFL DEC 0 6 2004 Plug Integrity D Subsequent Form Required: '-\'() ~ Approved byg) ¡;--/ A Form 10-4diS~3 V I OR\G\NALROF COMMISSIONER INSTRUCTIONS ON REVERSE THE COMMISSION Date ¡Jj3/4- Submit in Duplicate ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSI()~' APPLICATION FOR SUNDRY APPROVALS 1 2004 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 suspend~cIlJV,ell: . Time extension: . StimÛlâte: . Perforate: Other: .....Repáit¡;$'P 6. Datum elevation (DF or KB) / 90'JiSL 7. Unit or Property name / Redoubt Unit 2. Name of Operator Forest Oil Corporation. 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1918' FSL, 320' FEL, Sec. 14, T07N, R14W, SM At top of productive interval 2580' FNL, 758' FWL, Sec. 19, T07N, R13W, SM At effective depth 2787' FNL, 1145' FWL, Sec. 19, T07N, R13W, SM At total depth 2799' FNL, 1190' FWL, Sec. 19, T07N, R13W, SM 12. Present well condition summary Total depth: measured true vertical feet Casing Structural Conductor Surface 3,212' 133/8" 1020 bbl 3,212' 2,918' Intermediate 9,011' 95/8" 189 bbl 9,011' 7,534' Drilling Liner 5,561' 75/8" 35 b 14,320' 11,746' Production Liner 1,213' 5 1/2" 49 I 15,325' 12,601' Perforation depth: 14,420' -14,542',14,550'-14,612',14,682'-14,788', 14, 2'-14,834',14,840'-14,942', 14,948'-14,980', 14,974'-14,996', 15,002'- 15,020',15,014'-15,130',15,136'-15,152', 15,146'-1 192',15,228'-15,256' (MD) 33/8",6 spf 11,826' -11,926', 11,933'-11,984', 12,043'-12,132', 12, 7'-12,171', 12,176'-12,263', 12,269'-12,296', 12,291'-12,310', 12,315'-12,331', 12,326'-12,427',12,432'-12,482',12,512'-12,556' ( ) 3 3/8" TCP 6 spf Tubing (size, grade, and measured depth) 3 1/2" tubing se at 13,803' MD (32 jts P-11 0, 408 jts L-80) Length 200' Size 36" Cemented n/a 8. Well number Redoubt Unit #2 9. Permit number 201-031 10. API num r /' 50-733 0501-00 11. Fiel 001 Redoubt Shoal Oil Field Redoubt Shoal 15,325 ft 12,607 ft Plugs (measured) Effective depth: measured true vertical 15,218 ft 12,510 ft Junk (measured) S~~o/:L Measured depth 200' True vertical depth 200' 13. Attachements Description summary of proposa Detailed operations program: X BOP sketch: On File Packers and SSSV (type and measured depth) 14. Estimated date for commencing operation 12/112004 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 ~he foregoing is¡.rue and rrect to the best of my knowledge. Signed: ~ - t~ - Title: Production Engineer, Forest Oil FOR COMMISSION USE ONLY Conditions of approval: Notify Commissi so representative may witness Plug integrity- BOP Test--X- Location clearance Mechanical Integrity Tes - Subsequent form required 10- '-\'("' ~ Date: II ¡'J~t{ 3tY-! - ~ Approval No. Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE .~ :~ '.........", ~ ~ .iA Redoubt Unit ..) Completion - November 2002 .. TOL @ 8759 MD TOL @ 14112 MD Perforations: 14,420' -14,542' 14,550' -14,612' 14,682' -14,788' 14,782' -14,834' 14,840' -14,942' 14,948' -14,980' 14,974' -14,996' 15,002' -15,020' 15,014' -15,130' 15,136' -15,152' 15,146' -15,192' 15,228' -15,256' 3 3/8" 6 SPF fT ~ ~- .¡: .'- ~ ,.! ~ C ~ ') ~36" 150 # A-36 Welded 200 TVD 200 MD 133/8" 68# L-80 2918 TVD BTC 3212 MD 3 1/2" P-110 Pup 32jts 31/2" P-110 Tubing 24 jts 3 1/2" L-80 Tubing 3 1/2" L-80 Pup 384 jts 31/2" L80 Tubing 3 1/2" L-80 Pup ESP Assembly 95/8" 47# L-80 7534 TVD BTC 9011 MD Centrilift ESP Assembly (top of discharge head) @ 13803 MD LLC-3 Valve set in Baker Model FA Packer @ 14015 MD 7 5/8" L-80 11746 TVD 29.7 # Hydril521 14320 MD Perforations EZ Drill @ 15218 MD 51/2" 17# L-80 12601 TVD Hydril521 15325 MD ') Weatherford Forest Oil cor} Redoubt Unit #. Prepared For: Mr. Ted Kramer & Mr. Chuck Wilson Completion & Productiou Systems Prepared By: Lyle Savage & Mike Gray Date Prepared: 10-7-04 3-1/2" 12.9 ppfBTS-6 Tubing P-110 ESP Cable With Chemical Jnjecdon Line & Gas Vent l"uM Pup Joint 6' Length 3-1/2" 12.9 ppfBTS-6 P-II0 - Weatherford RIV Sliding Sleeve, Size 3-112" With 2.562" WR Profile 3-!l2" 12.9 ppfBl'S-6 Box]; Pin Pup Joint" Length 3-1/2" 12.9 ppfBT5-6 P-ll0 One Joint 3--1/2" 12,9 ppfBTS-6 Tubing P-119 Chemical Jøjectioa Line I ESP Cable I Gas Vent Tube Protector C1amps n n ~ Packer Top Sub S' Length 3-1/2" 12.9ppf BTS..6 Box Up P-110 F Gas Vent Line 3/8" OD x .049" WaU 316 Stainless Steet 3-112" Production String Chemical Injection Line 3/8" 00 x .049" Wall 316 Stainless Steel 318"GaSVl:ntTUbe~.. .. t ~ CahleCunnedorlOOAmpSKVWith3lC#2AWGCahle ESP Feedthrough . . 0 III Wea'herfurd 'Uydrow U-AP' Dual S.róng Uydraulie Set Retrievable Casing Patker With 3-112" 11.9 ppf 31S" Chemicallnje<:tion Line ~'" BTs.ó Box x Pin Production String, , 100 Amp 5KV Inlegral ESP Puwer Feedthrough. . . Two Eath 1/2" NP'l' Box x Pin Gas Vent I Chemical Injection Tubes With 46,600 Ib Straight Pull Shear Release 1111 6.672" OD x 5.67' LengthTo Fit 7-S/8" 24-29.7 ppfCasing ~ Vent IChemicallnjectiun Tube! With 1/2" NPT Pin Down 3-1{2" Producdon String ~ova Eng. Velocity valye. ~ ~ Nova Englaeerlng J" 0. D x 7.75" Length x 1/2" NPl' Velocity Check B - B Valves Installed On Chemkal Injection And Gas VentString!ì . L I!I. J ESP Feedtltrougb :- 0 \ Cable CunDcctor !60Amp SKV With3/C #2,'\WG C¡ablc . Packer Bottom Sub 6' Length 3-1/2" 12.9 ppf Bl's..6 Pin Down P-116 Nova Eug. Velocity Valve ~B' ~. ~ ~ iT ----- Re'C'irculzting hmp I Pump Intake 5.13'" OD 7.35' Lm!!f.b ~ .. z 0 ~ u.. 0:: w > 0 ...J !!:! u.. c::: 0 u.. '2:' « 0 Lr) .r; 0 eX; '<t" 0 0 N ~ N ;r One Juint3-1/2" 12.9 ppfBTS-6 Tubing P-118 Pup Joint 6' Length 3-112" 12.9 ppfBT8-6 P-IIO - Weatherford RlV Sliding Sleeve, Size 3-112" With 2.562" WR Profile 3-1/2" 12.9 ppfBTS-6 Box x Pin Pap .Ioint 6' Length 3..1/2" 12.9 ppfRTs-6 P..I 10 Minimum OneJoiDt3-1!2" J2.9 PllfBT5-6 Tubing P-110 Cro!cSQverSub 3-112" 12.' ppfBT5-6 Box x 3-1/2" EU Srd Pin Pressure Head 50S" 00 J; I' Length With 1/4" 00 Sensor Line Discharge Head 5.13" 00:1 05' Length P.mp, I 12Sbgc5.J3" 00 x 23.45' Lragth Ptomp. 112 Slage 5.13" OD 1 23.45' Leugth P.mp, III Sbge 5.13" 00 s 23.45' Length Seal 5.13" OD x 6.9' Length ~ m-------.----- 8<-.15.13" OD 1 6.9' Length ¡ I ¡ : :Motor 5.62" 00:1 33.85' Length 1 418 HI' 198 Amp 1 2.61 KY ~ Recireul.dan Tahe ~~----- $en.'IOr ".5" OD s 4.2' Lengtb With .'4" OD Sensor Line m:.===-::~~:~-=:~~ ~:::::':::d~:'~ ~~L::~:gth .) ) FO E 1 Oil P 11 ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #2 DATE: 11/22/04 . "~~~~'.:~i . "'l'iøl I. ESP/JET PUMP Install Completion General Information: Existing Casing: 9 5/8" 47# @ 9,011' MD 7 5/8" 29.7# @ 14,320' MD, Top of Liner @ 8,759' D 5 %" 17# @ 15,325' MD, Top of Liner@ 14, D Existing LLC Valve: Existing Bottom of ESP Motor: 13,803' MD* LLC-3 Valve set in Baker Model "FA" Packer @ 14,015' MD Existing Pump Type: Existing Press. Gauges: Existing Tubing: Existing Perforations: Proposed Tubin~:F Proposed Press. Gauges: Proposed ESP Motor: Proposed Pump Type: GC41 00 wI 266/KMHU Motor & MHL Motor Phoenix MS1 32 Joints 3 %" 9.3# P-110 8rd 408 Joints 3 %" 9.3# L-80 8rd 'V 14,420-14,54~D/11 ,826-11 ,926' TVD 14,550-14,612' MD/11,933-11,984' TVD 14,682-14,788' MD/12,043-12,132' TVD 14,782-14,834' MD/12,127-12,171'TVD 14,840-14,942' MD/12,176-12,263' TVD 14,948-14,980' MD/12,269-12,296' TVD 14,974-14,996' MD/12,291-12,310' TVD 15,002-15,020' MD/12,315-12,331' TVD 15,014-15,130' MD/12,326-12,427' TVD 15,136-15,192' MD/12,432-12,482' TVD 15,228-15,256' MD/12,512-15,256' TVD '%.(f" 3 %" 12.95# P-110 BTS-6 Phoenix MS1 Bottom of ESP Motor: 13,803' MD* 3-112 stage GC2900 with 418/ KMH Motor *AlI MD are based on the Nabors 429 drilling rig with a KB of 90 ft from Mean Low Water(MLW). The Kuukpik Rig #5 has a rig floor height of 29 ft. The upper deck height of Osprey Platform above MLW is 60 ft. These measurements may need to be adj~uste~.~Ii,ghtIY to allow for deck configuration but should be close. Prior to rig up of Kuukpik Rig #5, R # . ellbore will be bled down and circulated with produced water. The well has to be on production t perfo'?the no-flow-test. The No-flow test will occur after the well has been placed on production. 11/27/04 Page 1 of6 ) ,) F E T IL P 11 ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #2 DATE: 11/22/04 ¡f';~~~ ~..,' ~.I ~1,1 .'0i_""'~. .,~~ 1;:;;ý~~f.{~;~:." . Rig up Kuukpik Rig #5 1. Notify AOGCC for BOP Test. 2. Set BPV's and nipple down tree. 3. Move in and rig up Kuukpik Rig #5 with 13 5/8" BOP stack and test BOP's & rig tOA~~åOO PSI. Prior to Pulling ESP: Verify rig is centered over hole. ESP power cable will be damaged if rig is off center of hole. A pre job safety/planning meeting will be held prior to pulling the pump and at any crew change to ensure good communication 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. 46ea. 1.25" SS Bands, 7 ea. Unique Protectors, 15 ea. motor flat guards installed in this well. Please keep an accurate count of the amount pulled from the well. Pull equipment until a splice is reached and install a new cable reel. Continue pulling equipment while visually inspecting the cable and cut at splices. Clean threads, visually inspect and install thread protectors. Aiíbt., Current install shows 440 joints of 32 Joints 3 ~. 9.3# P-110 8rd, 408 Joints 3~" 9.3# L-80 8rd Equipment currently installed in the well Length (ft) ,.,,,,,,,,,..;OD(in) ID(in) a.) 1.0' 3.5"x5.5" --- Phoenix Discharge Pressure Head b.) 0.50' 5.13" 3.5" Discharge GPDIS 3.5" 8 Rd c.) 17.44' 5.13" Center Tandem Pump GC41 00 71 STAGE b d.) 17.44' 5.13" Center'andem Pump GC41 00 71 STAGE e.) 17.44' 5.13" Center Tandem Pump GC41 00 71 STAGE f.) 17.65' 5.13" Center Tandem Pump GC41 00 71 STAGE g.) 6.88' 5.13" Seal Section GSB3DBUTILH6PFSABHSN CL5 h.) 6.88' 5.13" Seal Section GSB3DBL TH6ABHSN CL5 %V i.) 22.88' 5.62" Motor 266 HP 1660/98 KMHU j.) 25.3' 5.62" Motor 304 HP 1900/98 KMHL k.) 5.02' 3.75" Phoenix MS1 Sensor (4.50" OD at Motor Flange) I.) 2.00' 5.85" Centralizer m.) Z~8' 3.00" Anode 1. 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. Page 2 of6 11/27/04 ) FORE T IL P ESP/JET PUMP RUNNING PROCEDURE -- Redoubt Unit #2 AFE # 045528 Revision #2 DATE: 11/22/04 ) l_::) 2. 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 ~.-_.-. 7 do not pull it (the retrieving tool will latch up automatically). Shoot fluid level in annulus prior to pulling the LLC ..-.'---""1: valve. After latch up - utilize bumper sub run above the retrieving tool to locate neutral p~i!.t. 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. Contingency - To release LLC Auto On / LH Off retrieving tool turn to the left while slowly picking up the tubing or work string. Once well has stabilized pull out of hole laying down 3 %" tubing and LLC valve. 3. 4. 5. 6. Ai 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 for submitting to Forest Oil's Representative a Complete Tubina Detail to include the following information: ~v . Number and length of each joint . Another downhole equipment installed in the tubing string . Number & location of each clamp . Number of electrical splices and location. r 3. A Centrilift representative must be on location when the ESP is assembled and when hanger penetrations are made. Company 4. Place cable on the spooler, in an area that is in direct view of the rig operator; make the motor flat splice prior to job commencement. 5. Confirm that the sheave is 54" in diameter and the safe~ cable is attached to sheave. Normal running height shall not exceed 40' above floor. Þ 6. NOTE: The flat cable should be hand fed to the floor and the round cable tied off at the floor until the flat round splice is secured to the tubing to minimize stress on the flat/round splice. 7. Do not handle the cable spool with slings in direct contact with the cable. 8. Use pre-formed Superbands sparingly to secure the flat cable alongside the equipment. 9. Do not allow the tubing to turn while making connections or while TIH with the ESP. Back up all connections while TIH. 10. Exercise extreme caution to avoid jarring or bending equipment when moving to rig floor. 11. The hole shall be covered at all times when cable bands or clamps are being installed. 12. TIH with ESP no faš_than 1 it/min (1800 ftlhr). Exercise extreme caution when TIH to avoid sudden starts and stops which may damage cable (especially when setting slips/spider). NOTE: A Hot work permit is required for testing the ESP and cables. 13. Conductivity tests shall be performed on the cable every 2,000 feet while RIH. Note: Conductivity tests have been corrupted on other Cook Inlet Platforms due to the Platform cathodic protection system. This system may need to be disabled temporarily. Operations shall be immediately shut down and the cable visually inspected and a conductivity test performed any time a severe pull is noted. Page 30f6 11/27/04 ) ) FO EST IL P TI ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #2 DATE: 11/22/04 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. 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 center of 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 will be on the Rig floor at all times during the running of the ESP and will be responsible for ensuring that cable is kept free when setting the slips. NOTE: It is absolutely essential that all clamps and bands used to install the ESP cable be counted documented location and reported accurately so that there can be no confusion concerning the number of 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 all times until on the catwalk. 2. ALL ESP AND CABLE movement shall be witnessed and approved by Centrilift Service rep. 3. Motor, seal and pump boxes shall be supported by three equally spaced rests or on a flat surface whenever in storage or shipment. 4. Move the pump, motor and seal sections up to rig individually. %<&T ~. Page 4 of 6 11/27/04 ) ) FO EST IL C P TI ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #2 DATE: 11/22/04 ~::::) BOTTOM HOLE ASSEMBLY RUNNING PROCEDURE Bottom Hole Assembly consisting of the following: a.) b.) c.) d.) e.) f.) g.) h.) i.) j.) k.) I.) m.) n.) 0.) p.) q.) r.) s.) t.) u.) v.) w.) x.) Length(ft) OD(in) ID(in) 3.00' 3.00" 2.00' 6.00" 4.20' 4.50" 33.85' 5.62" 6.9' 5.13" 6.9' 5.13" 23.45' 5.13" 23.45' 5.13" 23.45' 5.13" tfl!}¿;.;:;; 0.50' 5.5"X3.5' :~ih 1.00' 5.5" 1.00' 3.5" Anode 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 30.00' . <:%'?~~~" 2.75" 1- Joint of Tubing 12.9 # BTS-6 6.00,';.::"~ ...,;3.5", 2.75" Pup Joint 3.5" 12.9 # BTS-6 . 3.2Ó'> 5" 2.562" ~~atheñord RIV(Sliding Sleeve) wI 2.562 R profile ..: ~~~?' 3.5'" 2.75" PUP:d~int 3-112" 12.9# BTS-6 3Ô~OO'" 3.5": .,2.7~? '¡ : 1 ~ J()~.nrof Tubing 12.9 # BTS-6 12.00' .. .3.5" 2.75".;:I:'.~pJoint 3-112" 12.9# BTS-6 8.27' 7 5(~"X 3-112" X 1.9" Weatherford Hydrow 11- Dual String Packer 12.00' 3.5~; 2.75" Pup Joint 3-112" 12.9# BTS-6 ..~ 30.00' 3.5".":~,~;;2. 75" 1- Joint of Tubing 12.9 # BTS-6 6.00' 3.5" 2.75" Pup Joint 3-112" 12.9# BTS-6 3.2' 3.5" 2.13" Weatheñord RIV(Sliding Sleeve) wI 2.13 X profile 6.00' 3.5" 2.75" Pup Joint 3-112" 12.9# BTS-6 Note: 7518" Top of Uñtf@8,759' 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. 11/27/04 Page 5 of 6 ) ) FO EST Il C P ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #2 DATE: 11/22/04 i;~r~'~t\:. "1.4 :ifj .Ò\\'~..h:~~/P 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. 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 attaching Unique clamps & guards to secure the equipment. 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 crossover from 8 rd to BTS-6 on top of Phoenix discharge pressure head. 8. Run in hole with one joint of 3 %" 12.95# P-110 BTS-6 tubing. "1f'" 9. Recommended torque values for 3-1/2" 12.95#/ft P-110 BTS-6 are: ~nimum = 7,000 ft-Ib. Maximum = 8,800 ft-Ib. 10. Pick -up Weatherford RIV sliding sleeve with 2.562 R Profile with a 6' pups above and below and run in hole. 11. Run in hole with one joint Ok.~" 12.95# P-11 0 BTS-6. 'wfr 12. Pick-up Weatherford Hydrow II - dual string packer with 12'pups above and below. A BIW feed through power cable will be pig tailed and ready for additional connection above and below the packer. There are two %" NPT connections with Box by Pin connection. Make connection of the NOVA Double Check valves to the chemical injection lines below the packer. 13. Run on.~ joint of 3 %" 12.95# P-11 0 BTS-6 above the Twin Seal Packer. 14. Pick -up Weatherford RIV sliding sleeve with 2.562" R Profile with 6' pups above and below and run in hole. 15. Run in hole with 3-1/2" 12.95# P-110 BTS-6 Production Tubing as required for ESP setting depth. The bottom of ESP motor at plus or minus 13.803' MD. Conductivity tests shall be peñormed on the cable every 2,000 feet while RIH. 16. Run in hole with plug on wireline to set in bottom sliding sleeve, pressure up on it and the packer will set it. .17. Place 20,000 1bs 'lÆigr¡t {in cOinpress:on) on the packer. This weight is needed for the future operations of the Jet Pump. .WÆW 18. Place one drum of Báker packer fluid on the backside of well. 19. Tubing hanger with 3-1/2" 12.95# P-11 0 BTS-6 pup joint, ESP power cable Penatrator, CAP Tube penetrator. Page 6 of 6 11/27/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #1 DATE: 8/18/04 ) I. ESP/JET PUMP Install Completion General Information: Existing Casing: Phoenix MS1 95/8" 47# @ 9,011' MD 75/8" 29.7# @ 14,320' MD, Top of Liner@ 8,759' D 5 %" 17# @ 15,325' MD, Top of Liner@ 14,1 ' MD Existing LLC Valve: Existing Bottom of ESP Motor: 13,803' MD* LLC-3 Valve set in Baker Model "FA" P Existing Pump Type: Existing Press. Gauges: Existing Tubing: Existing Perforations: Proposed Tubing: Proposed Press. Gauges: Proposed ESP Motor: Proposed Pump Type: Proposed LLC Valve: (NOTE IF REQUIRED) GC41 00 wI 266/KMHU Motor & 3041 32 Joints 3 %" 9.3# P-11 0 81': 408 Joints 3 %" 9.3# L-80 d '7..Jp~QU:~~ \\.(;;3 14,420-14,542' MD/11, 6-11,926' TVD 14,550-14,612' MD/1 33-11,984' TVD 14,682-14,788' MDI ,043-12,132' TVD 14,782-14,834' M 12,127 -12,171 'TVD 14,840-14,942' /12,176-12,263' TVD 14,948-14,980' D/12,269-12,296' TVD 14,974-14,99 MD/12,291-12,310'TVD 15,002-15, 0' MD/12,315-12,331' TVD 15,014-15 30' MD/12,326-12,427' TVD 15,136- ,192' MD/12,432-12,482' TVD 15,228 5,256' MD/12,512-15,256' TVD Bottom of ESP Motor: 13,803' MD* 3-112 stage GC2900 with 4181 KMH Motor LLC-3 Valve set in Baker Model "FÞ:' Packer@ 14,015' MD *AlI MD are based n the Nabors 429 drilling rig with a KB of 90 ft from Mean Low Water(MLW). The Kuukpik Ri has a rig floor height of 29 ft. The upper deck height of Osprey Platform above MLW is 60 ft. These measurement may need to be adjusted slightly to allow for deck configuration but should be close. Prior lì of Kuukpik Rig #5, RU #6 wellbore will be bled down and circulated with produced water. 11/18/04 Page 1 of6 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #1 DATE: 8/18/04 Rig up Kuukpik Rig #5 ) 1. Notify AOGCC for BOP Test. 2. MIRU Kuukpik Rig #5. 3. Set BPV and nipple down tree. N/U 13-5/8", 5K BOP stack and test. . C\ \\ \C ~0~~,~~~ ~.~ Verify rig is centered over hole. ESP power cable will be damaged if rig is off center of ole. A pre job safety/planning meeting will be held prior to pulling the pump and at any crew change to ensure good". mmunication between all parties on location. A Centrilift representative will be on the rig floor at all times during;-1he pulling of the ESP and will be responsible for ensuring that cable is kept free when setting the slips. ,/ I' NOTE: Install records show that there are 236 ea. Cannon clamps, 46eà. y~~" SS Bands, 7 ea. Unique Protectors, 15 ea. motor flat guards installed in this well. Please keep an accurate count6f the amount pulled from the well. .,,/' " Pull equipment until a splice is reached and install a new cable reel. I.~bntinue pulling equipment while visually inspecting the cable and cut at splices. Clean threads, visually inspect and inJéll thread protectors. /' Current install shows 440 joints of 32 Joints 3 ~"9.3# P-110 8rA', 408 Joints 3~" 9.3# L-80 8rd / l ,,,,l l ;' OD(in) ID(ir))' 3.S"xS.S" ¡ Phoenix Discharge Pressure Head 5.13" 1.5" 5.13/". . --- 5.13" 5.1 " Prior to Pulling ESP: Equipment currently installed in the well a.) b.) c.) d.) e.) t.) g.) h.) i.) j.) k.) I.) m.) Length (tt) 1.0' 0.50' 17.44' Discharge GPDIS 3.5" 8 Rd Center Tandem Pump GC41 00 71 STAGE Center Tandem Pump GC41 00 71 STAGE Center Tandem Pump GC41 00 71 STAGE Center Tandem Pump GC4100 71 STAGE Seal Section GSB3DBUTILH6PFSABHSN CL5 Seal Section GSB3DBL TH6ABHSN CL5 17.44' 17.44' 17.65' 6.88' 5.13" 5.62" Motor 266 HP 1660/98 KMHU Motor 304 HP 1900/98 KMHL Phoenix MS1 Sensor (4.50" OD at Motor Flange) 5.62" 3.75" Centralizer Anode 5.85" 3.00" 1. Pull out of hol , racking back the 3 ~" tubing, and laying down ESP Pump/Motor and reeling up the ESP electrical cable. Ma note of any indication of electrical failure on the cable. 11/18/04 Page 2 of6 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #1 DATE: 8/18/04 ) //-,/ 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 for submitting to Fores Representative a Complete TubinQ Detail to include the following information: C\ C\ HI "7 -JçcrcftjCX;l {Y3 . Number and length of each joint . Another 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 as made. 4. Place cable on the spooler, in an area that is in direct view of e rig operator; make the motor flat splice prior to job commencement. 5. Confirm that the sheave is 54" in diameter and the sa~ cable is attached to sheave. Normal running height shall not exceed 40' above floor. /mbled and when hanger penetrations are 6. NOTE: The flat cable should be hand fed to the fI r and the round cable tied off at the floor until the flat round splice is secured to the tubing to minimize stress the flat/round splice. 7. Do not handle the cable spool with slings in dir: ct contact with the cable. 8. Use pre-formed Superbands sparingly to sure the flat cable alongside the equipment. 9. Do not allow the tubing to turn while aking connections or while TIH with the ESP. Back up all connections while TIH. 10. Exercise extreme caution to avoid' rring or bending equipment when moving to rig floor. 11. The hole shall be covered at all mes when cable bands or clamps are being installed. 12. TIH with ESP no faster than jt/min (1800 fVhr). Exercise extreme caution when TIH to avoid sudden starts and stops which may damage ble (especially when setting slips/spider). 13. Conductivity tests shall e performed on the cable every 2,000 feet while RIH. Note: Conductivity tests have been corrupted on oth Cook Inlet Platforms due to the Platform cathodic protection system. This system may need to be disabled mporarily. Operations shall be immediately shut down and the cable visually inspected and a conductivity t st performed any time a severe pull is noted. . 14. While electrical ecks are being made, break Circulation through the pump to assure pump is clear of foreign material. Rate ould not exceed 1.5 bpm at 1500 psi. 15. Exercise ca Ion to insure slips will not be set on either the ESP or cable. Damage to the cable will require that the installa' n is stopped and the cable repaired. Assign one man on the Rig floor to be responsible for watching the cable hen lowering into well. 16. DO N allow the cable to drag across rough edges while TIH. 17. ~ Tst representative shall witness free rotation of completely assembled ESP unit on Rig floor. Prior tïunning ESP: Lay ~t and strap all equipment. A pre job safety/planning meeting will be held prior to running the pump and at any cre,? change to ensure good communication between all parties on location. A Centrilift representative will be on the rig Page 3 of 6 11/18/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #1 DATE: 8/18/04 ) floor at all times during the running of the ESP and will be responsible for ensuring that cable is k the slips. NOTE: It is absolutely essential that all clamps and bands used to install the ESP cable be unted with a documented location and reported accurately so that there can be no confusion concerning the numb of bands in the well if the completion needs to be pulled in the future. Schematics of all clamps will be included Ith the checklists and count. 1. Exercise caution when handling the seal, motor and pumps sections to m" imize bending. Use at least two lift pOints when moving horizontally. Equipment shall be moved in boxes at a imes until on the catwalk. 2. ALL ESP AND CABLE movement shall be witnessed and approved b~ntrilift Service rep. 3. Motor, seal and pump boxes shall be supported by three equall ."aced rests or on a flat surface whenever in storage or shipment. 4. Move the pump, motor and seal sections up to rig individually' S0p((:~e~ l~? BOTTOM HOLE ASSEMBLY RUNNING PROC Bottom Hole Assembly consisting of the foil Length(ft) OD(in) ID(i 3.00' 3.00" a.) b.) c.) d.) e.) f.) g.) 2.00' 6.00" 4.20' 33.85' 6.9' 6.9' 23.45' Anode Centralizer Phoenix MS1 Sensor (4.50" OD at Motor Flange) Motor 418 HP 2610/98 KMH Seal Section GSB3DB EHLH6ABHUKPFSAMNLLT Seal Section GSB3DB EHLH6ABHUKPFSAMNLUT Lower Tandem Pump GC2900 112 STAGE wI Inconel Shaft h.) 5.13" Center Tandem Pump GC2900 112 STAGE wI Monel Shaft i.) 5.13" Upper Tandem Pump GC2900 112 STAGE wI Monel Shaft j.) 5.5"X3.5" --- Discharge GPDIS 3.5" 8 Rd k.) 5.5" Pressure Head I.) 1.00' 3.5" Cross over Sub 3.5" 12.9 # BTS-6 box to 8rd Pin m.) 30.00' 3.5" 2.75" 1- Joint of Tubing 12.9 # BTS-6 n.) 6.00' 3.5" 2.75" Pup Joint 3.5" 12.9 # BTS-6 0.) 3.20' 5" 2.562" Weatherford RIV(Sliding Sleeve) wI 2.562 R profile p. 6.00' 3.5" 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 r.) 12.00' 3.5" 2.75" Pup Joint 3-1/2" 12.9# BTS-6 s.) 8.27' 7 5/8"X 3-1/2" X 1.9" Weatherford Hydrow 11- Dual String Packer 11/18/04 Page 4 of 6 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #1 DATE: 8/18/04 ) t.) 12.00' 3.5" 2.75" Pup Joint 3-1/2" 12.9# BTS-6 u.) 30.00' 3.5" 2.75" 1- Joint of Tubing 12.9 # BTS-6 v.) 6.00' 3.5" 2.75" Pup Joint 3-1/2" 12.9# BTS-6 w.) 3.2' 3.5" 2.13" Weatherford RIV(Sliding SI ve) w/2.13 X profile x.) 6.00' 3.5" 2.75" Pup Joint 3-1/2" 12.9# B -6 Note: 75/8" Top of Liner @ 8,759' MD ~0~~£h~ \y)") 1. Pick up the 418 Hp ESP motor (33.85') and attach the Phoenix 81 (4.20') to the bottom with the Unique Stand-off attached to the bolts at 180 deg opposite the motor thead terminal. Screw a centralizer (2.0') into the bottom of the Phoenix MS1. Attach anode to centralizer .0'). This assembly will be 43.05' in length. 2. Slowly lower the motor assembly into the well and lower' ing clamp onto the wellhead slips. Assemble the seal (13.8') and lower assembly onto the motor. Line up as mbly alignment marks at the seal. 3. Service the seal and the motor as per standard se cing procedures as outlined in the Baker Centrilift Technical Service Manual. 4. Attach the motor flat as per standard procedur and attach the proper Unique protection clamp at the lower flange of the Seal section. 5. Continue installing into the well with the I er pump, center pump and the upper pump attaching Unique clamps & guards to secure the equipment. 6. Do not allow the tubing to turn whil making connections or while TIH with the ESP. Back up all connections while TIH. 7. Install crossover from 8 rd to BT -6 on top of Phoenix discharge pressure head. 8. Run in hole with one joint of 3 1 2' 12.95# P-11 0 BTS-6 tubing. 9. Recommended torque valu s 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 IV sliding sleeve with 2.562 R Profile with a 6' pups above and below and run in hole. 11. Run in hole with 0 joint of 3 Y2' 12.95# P-110 BTS-6. 12. Pick-up Weath ord Hydrow II - dual string packer with 12'pups above and below. A BIW feed through power cable will be p' tailed and ready for additional connection above and below the packer. There are two Y2' NPT connections ith Box by Pin connection. Make connection of the NOVA Double Check valves to the chemical injection Ii s below the packer. 13. Run on joint of 3}'2" 12.95# P-110 BTS-6 above the Twin Seal Packer. p Weatherford RIV sliding sleeve with 2.562" R Profile with 6' pups above and below and run in hole. Page 5 of 6 11/18/04 ) FOREST OIL CORPORATION ESP/JET PUMP RUNNING PROCEDURE - Redoubt Unit #2 AFE # 045528 Revision #1 DATE: 8/18/04 ) 'J~~I"'!~~" /l'/ 15. Run in hole with 3-1/2" 12.95# P-110 BTS-6 Production Tubing as required for ESP setting,-depth. The bottom of ESP motor at plus or minus 13,803' MD. Conductivity tests shall be performed on.,tlÍe cable every 2,000 feet while RIH./:",/ ,,¡'/ 16. Run in hole with plug on wireline to set in bottom sliding sleeve, pressure up on it.'¿nd the packer will set it. ~/,¡¡l! 17. Place 20,000 Ibs weight (in compression) on the packer. This weight is nee,Ø"td for the future operations of the Jet Pump./,/i' l ,~/l' 18. Place one drum of Baker packer fluid on the backside of well. l,l' ,/ 19. Tubing hanger with 3-1/2" 12.95# P-110 BTS-6 pup joint, ESP p.s>Wer cable Penatrator, CAP Tube penetrator. l // 20. Set BPV, N/D BOPE, N/U and test tree. Release rig. /l / .,/ ,:¡I /'/ (\ (\~ l'/ c,. \),)~.C@èç)r .. ,/ I'" ,/ II / / ;/ ! Page 6 of 6 11/18/04 ~ Subject: Latest RU #1 and SA Sundri~s 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> ') I ) Latest RU #3 and 5A Sundries 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 1, 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 Re: RU #2 ,~ ~ Subject: Re: RU #2 From: Thomas Maunder <tom- maunder@admin.state.ak.us> Date: Thu, 03 Jun 200407:46:29 -0800 To: Bill Penrose <bill@fairweather.com> CC: "Paula Inman (PRInman@forestoil.com)" <PRInman@forestoil.com>, "Roy Smith (RLSmith@forestoil. com)" <RLSmith@forestoil.com> Bill, Acknowledgment that any deviations from the regulations must be approved in writing is appreciated. I will forward the sundry for approval. What is the timing of starting the work?? The responsible supervisors need to stay in touch with Jim Regg (jim regg@admin.state.ak.us) and the Inspectors (aogcc prudhoe bay@admin.state.ak.us) regarding witnessing the BOP test. As much notice a'š-.po.sI3Ibi.e would-be--ãppreci'ated so that schedules can be coordinated. Tom Maunder, PE AOGCC Bill Penrose wrote: Tom, Our teleconference with Cudd and your most recent discussion with them are all aimed at ensuring that every aspect of the BOPs and BOPE control system is completely in accord with the AOGCC's rules. The only waiver that is requested is the one concerning the use of manual chokes (to which you've indicated the AOGCC has no objection) and that waiver request is contained in the sundry. Since Forest Oil acknowledges that dev¡ations from the AOGCC's regs that are not approved in the sundry or otherwise in writing are not permissible, would it be acceptable to you to release the approved sundry while continuing to work with Cudd and Forest Oil to ensure tHe BOP system meets the AOGCC's requirements? Regards, Bill -----Original Message----- From: Thomas Maunder [mailto:tom 03, 2004 7:15 AM To: Bill Penrose Subject: RU #2 maunder@admin.state.ak.us] Sent: Thursday, June Bill, Sorry I wasn't able to get back to you yesterday. Since we last talked, I have talked to Cudd. Last I heard, they were getting a "high pressure hose" to eliminate as many connections as possible in the choke and kill lines. I still have the sundry. A request is made in the sundry to employ manual chokes and that is acceptable. I had expected to get some further information/report on the choke/kill line resolution and then forward the sundry for approval. Have you heard any other information?? Tom 1 of 1 6/3/2004 8:22 AM ~ 1""""'\ @ FOREST OIL CORPORATION .J10 dYC 61l~é. c:57uüe 700 cPtnc~, ~1ca!}!}501 (.907) 2/;8-8600 . (.907) 258-8601 (~x) May 24, 2004 ,*O~-D3 } Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: RU #2 ESP Repair Dear Mr. Norman, The Electric Submersible Pump (ESP) in the Redoubt Unit #2 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. Sincerely, i2&~~ Paula Inman Production Engineer Forest Oil Corporation Attachments: 10-403 Application for Sundry Approvals Outline Procedure Wellbore Schematic - RU #2 13-5/8" 5M BOP Schematic Snubbing Circulation Schematic Snubbing Equipment Layout OR\G\NAl RECEIVED MAY 242004 Alaska Oil & Gas Cons. Commission Anchorage ,,--..., 1""""'\ ~~3 .-~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: - Operation shutdown: Alter casing: Repair well: Plugging: Change approved program: Pull tubing: X Vaiiãñce: 5. Type of well: Development: -!.. Exploratory: Stratigraphic: Service: Re-enter suspended well: Time extension: Stimulate: Perforate: Other: Repair ESP 6. Datum elevation (DF or KB) 2. Name of Operator Forest Oil Corporation. 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1918' FSL, 320' FEL, Sec. 14, T07N, R14W, SM At top of productive interval 2580' FNL, 758' FWL, Sec. 19, T07N, R13W, SM At effective depth 2787' FNL, 1145' FWL, Sec. 19, T07N, R13W, SM At total depth 2799' FNL, 1190' 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 #2 9. Permit number 201-031 10. API number 50-733-20501-00 11. Field/Pool Redoubt Shoal Oil Field Redoubt Shoal 15,325 ft 12,607 ft Plugs (measured) Bridge plug at 15,218'MD Effective depth: measured true vertical 15,218 ft 12,510 ft Junk (measured) N/A Casing Structural Conductor Surface 3,212' 133/8" 1020 bbl 3,212' 2,918' Intermediate 9,011' 95/8" 189 bbl 9,011' 7,534' Drilling Liner 5,561' 75/8" 35 bbl 14,320' 11,746' Production Liner 1,213' 51/2" 49 bbl 15,325' 12,601' Perforation depth: 14,420' -14,542', 14,550'-14,612', 14,682'-14,788', 14,782'-14,834', 14,840'-14,942', 14,948'-14,980', 14,974'-14,996', 15,002'- 15,020', 15,014'-15,130',15,136'-15,152', 15,146'-15,192', 15,228'-15,256' (MD) 33/8",6 spf 11,831'-11,931',11,938'-11,989', 12,048'-12,136', 12,133'-12,177', 12,182'-12,268', 12,274'-12,301',12,296'-12,315', 12,324'-12,340', 12,331'-12,431',12,437'-12,451', 12,447'-12,488', 12,519'-12,544' (TVD) 3 3/8" TCP 6 spf Tubing (size, grade, and measured depth) 31/2" tubing set at 13,803' MD (32 jts P-110, 408 jts L-80) Length 200' Size 36" Cemented nla Measured depth 200' True vertical depth 200' Packers and SSSV (type and measured depth) Baker FA packerw/ LLC-3 valve set @ 14,015' MD 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 6/1/2004 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 certify that the foregoing is true and correct to the best of my knowledge. Signed: ~- ~ ~ Title: Production Engineer, Forest Oil Date: 5: ~'1' /0 '-I FOR COMMISSION USE ONLY I Co Conditions of approval: Notify Commission so repres)(tive may witness APprovall-.l If.. /' Plug integrity- BOP Test Location clearance- , LfWf' . "I..:. Mechanical Integrity Test- Subsequent form required 10- '-'Gl-\ I.~~~~i.\a,-\o ~~,\-,,~~~ \~\\-,ú\ ~<:>\c\ RE Q<t~\~ "'t<t)("O~\\~ c.."~~ ~ ~~\~~ CEIVED ê) MAY 2 4 2004 Approved by order of the commissione~ / ;~- .,/' .. ~~Il~' fIIlMS conSn!ìmnmzf:' tJf '--'"""" Bf~ ,-' jU" jij" @:Wnqt{PJage Form 10-403 Rev 06/15/88 ;' ~\j~~) ~L SUBMIT IN T IPLICA TE ^,",I^"" A I ,,--..., r'\ REQUEST FOR WAIVER RU #2 ESP Repair Forest Oil plans to use a Cudd 340K Hydraulic Pulling Unit to pull the failed ESP assembly in Well RU #2 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 ~ have a remotely controlled hydraulic choke. Choke operation on this unit is v' two dundant, manually operated chokes located at the choke manifold. r - It is Forest Oil's position that the unit's choke and kill system as currently configured is sufficient for work on RU #2 and similar wells on Osprey Platform due to the under- pressured character of the reservoir. RU #2 is currently dead with only crude oil and produced water in the wellbore. Recent fluid levels shot in the w ell indicate that the existin~ LLC valve is functioning and supporting the fluid column. Before commencing the planned ESP replacement work, the well will be displaced with produced water and will remain full due to the LLC valve. 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. 1: ~~",,-~~-o."V~-..c. \ ~ ~~ Of'.. '7 vv-.o. "" ""- \ cl--a ~. ..42 ~ ~ ~f"!-O~ ORIGINAL I """.,- "\1 1\ I r-.. 1""""'\ Redoubt Unit #2 - ESP Repair Outline Summary 1. Bleed off gas head in tubing and annulus. 2. Fill tubing and annulus with produced water. - ,,<t,,\~ ~<"L \\ \. ~ ~~\-\c:..... 3. Nipple Down 3-1/8" production tree. - 'YL -\- ~ ~--J 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 Leg 3, Slot #2. l' , 6. Pull 3" BPV. ~ c...b\N\~\~\ \ 7. Pull tubing hanger and 3 W' ESP Completion. ~ A- ;: ~ ~ 8. Run new 3-W' ESP Completion. "'-.)~ 'f"\~':>,,;> "'ï ~c<;';\\J ~ 9. Set 3" BPV in tubing hanger. 10. Nipple down 13 5/8" BOPE and riser. 11. Nipple up and test 3-1/8" production tree. 12. Pull BPV. 13. Turn over well to production crew. Redoubt Unit ... TaL @ 8759 MD TaL @ 14112 MD Perforations: 14,420' -14,542' 14,550' -14,612' 14,682' -14,788' 14,782' -14,834' 14,840' -14,942' 14,948' -14,980' 14,974' -14,996' 15,002' -15,020' 15,014' -15,130' 15,136' -15,152' 15,146' -15,192' 15,228' -15,256' 3 3/8" 6 SPF Completion ~ November 2002 iii.. 36" 150 # A-36 Welded 133/8" 68# 31/2"P-110Pup 32jts31/2"P-110Tubing 24 its 3 1/2" L-80 Tubing 31/2" L-80 Pup 384 its 3 1/2" L80 Tubing 3 1/2" L-80 Pup ESP Assembly 95/8" 47# Centrilift ESP Assembly (top of discharge head) @ 13803 MD LLC-3 Valve set in Baker Model FA Packer @ 14015 MD 75/8" 29.7# 200 TVD 200 MD L-80 BTC 2918 TVD 3212 MD L-80 BTC 7534 TVD 9011 MD L-80 11746 TVD Hydril521 14320 MD Perforations E.ZDrill@ 15218 MD 51/2" 17# L-80 Hydril 521 12601 TVD 15325 MD FromMudPwnp; Of: . . . To Kelley .- Hose . . 1 . . . 1 . Standpipe o)i' ;¡J -- 1-1 0"": ~ " . . . . . To Casing Valve ,.... ToGas Bustc' 2" FiJI Une From Trip Tank 4" Return Line To Trip Tank 1 ofI!~¡¡ 11' f Kill Line ¡ To Gas Bust" To Mud Tank I RE: AOGCC Feedback on Cudd Unit BOPE Modifications ~ "" Subject: RE: AOGCC Feedback on Cudd Unit BOPE Modifications From: Roy Smith <RLSmith@forestoi1.com> Date: Fri, 21 May 2004 16:04:21 -0600 To: "'rautin@cudd.com'" <rautin@cudd.com>, "'hans@pattersonservices.com'" <hans@pattersonservices.com> CC: "Tom Maunder (tom_maunder@admin.state.ak.us)" <tom_maunder@admin.state.ak.us>, 'Bill Penrose' <bill@fairweather.com> Richard/Micky Attached are issues that must be addressed and corrected for the upcoming operation for the ESP pump change out RU # 2, on the Osprey platform. Please insure each of these issues is addressed and followed, regarding rig-up and testing of equipment. Please contact me regarding any questions. Thanks! -----Original Message----- From: Bill Penrose [mailto:bill@fairweather.com] Sent: Friday, May 21, 2004 3:42 PM To: Roy Smith (RLSmith@forestoil.com) Cc: Tom Maunder (tom_maunder@admin.state.ak,us) Subject: AOGCC Feedback on Cudd Unit BOPE Modifications Roy, The Alaska Oil & Gas Conservation Commission verbally provided the following comments to me upon hearing that the Cudd hydraulic unit would again be used for a workover in Cook Inlet. The choke and kill lines have to be rigid steel pipe with flanged connections. Armored flexible hose is also allowed but still must be connected with flanges. "Internally clamped swivel joints" are not allowed. I'm trying to get hold of somebody at the Commission to help with a definition of "internally clamped swivel joints". They addressed the high failure rate initially experienced with the choke manifold. You and I agree that the cause (non-arctic grease) has been resolved by switching to fresh, arctic grade grease. Accumulator pressure recovery time: the AOGCC prefers to see the maximum recovery time for accumulators be 3-4 minutes. The Cudd accumulator presently takes right at 4 minutes to recover and that causes the Commission some concern. To answer your question, the rules governing the accumulator are: BOPE systems must include a hydraulic actuating system with (i) sufficient accumulator capacity to supply 150 percent of the volume necessary to close all BOPs, except blind rams, and to open the remotely controlled hydraulic valve while maintaining a minimum pressure of 200 psi above the required precharge pressure when all BOPs, except the blind rams, are closed and all the power sources are shut off; and (ii) an accumulator pump system consisting of two or more pumps with independent primary and secondary power sources and an accumulator backup system having sufficient capacity to close all BOPs and hold them closed. This doesn't make it clear to me how much of any given BOP stack has to be shut in before beginning the timing of accumulator recovery. I'll get a reading from the Commission. The AOGCC would like to have the rig crew test the BOP bodies to the required working pressure before the inspector is called out. This will allow the crew to correct most of any deficiencies before the inspector arrives. They point out that all requests for waivers to the printed regulations must be submitted in writing 10f2 6/3/2004 8:25 AM RE: AOGCC Feedback on Cudd Unit BOPE Modifications ,1"""\ ~ and they will respond in writing. This will eliminate any confusion during inspections and operations. They will be enforcing the 7 -day schedule for BOP tests. BOPE can be tested on, say. day 5 or 6 of the 7 -day cycle, thus resetting the 7 -day clock, but the time period between tests may not exceed 7 days. Regards, Bill 2 of2 6/3/2004 8:25 AM [Fwd: BOP CUDD 131 / OSPREY 3/10/04] r-"\ ,~ Subject: [Fwd: BOP CUDD 131 / OSPREY 3/10/04] From: James Regg <jimJegg@admin.state.ak.us> Date: Thu, 11 Mar 2004 14:28:57 -0900 To: Tom Maunder <tom_maunder@admin.state.ak.us>, Winton GAubert <winton - aubert@admin.state.ak.us> "deja vu allover again"; the BOPE test failures on this unit 1/24/04 - Tested 24 components; *16* failures (AOGCC witness) 2/02/04 - Tested 24 components; *7* failures 2/11/04 - Tested 24 components; *1* failure 2/21/04 - Tested 24 components; *4* failures (AOGCC witness) 2/29/04 - Tested 24 components; *1* failure 3/10/04 - Tested 24 components; *8* failures thus far: Failure rate is about 25%; mainly attributed to non-ram equipment such as choke manifold valves, chicksan, kill line, stand pipe, etc. Sad part is that there are repeat failures - e.g., C-5 valve replaced 2/21, failed test 2/29; P-6 has failed numerous times; there are others. Performance is substandard and we should not allow this type of equipment arrangement for future applications of this or similar rigs. Jim -------- Original Message -------- Subject: BOP CUDD 131 / OSPREY 3/10/04 Date: Thu, 11 Mar 2004 15:35:18 -0700 From: Osprey Company Man <OspreyCM@forestoil.com> To: AOGCC Prudhoe (~ogcc prudhoe bay@admin.state~~k~~~) <aogcc prudhoe bay@admin.sLate.ak.us> CC: Bob Fleckenstein (bob fleckenstein@admín.state.ak.us) <bob fleckensteín@admín. state:a-k-.-üs>, Jim ReggTj ím regg@ãdmin. state. ak. us) <jím regg@admin.sta~~~~~~2' Tom Maunder (to~_mau~Q~r@admín.s~ate.ak.us) <tom maunder@admín.state.ak.us> --- ------ ---------- ----------- --------- - - -------- , Content-Type: applicationlvnd.ms-excel BOP TEST CUDD 1313-10-2004.xls' C E d. b 64 ontent- nco mg: ase -- - - - - - - - ------------ -- -- - ----- - - - ----- - - ----- - -- - - - -- - - --- - ---- --- ------ - - -- --- -- --. 1 of 1 6/3/2004 8:26 AM Permit to Drill 2010310 DATA SUBMITTAL COMPLIANCE REPORT 7/2112003 Well Name/No. REDOUBT UNIT 2 Operator FOREST OIL CORP APl No. 50-733-20501-00-00 MD 15325-~ TVD 12601 J Completion Dat 6/27/2001 .--~' Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_po Sample N__9 Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt c (data taken from Logs Portion of Master Well Data Maint) C C Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments ~f'~1 FINAL 8998 15036 CH 7/6/2001 ~?O'i'~' ~0~180 FINAL 12770 14717 CH 7/6/2001 ~ 80 .....1J3179 FINAL 1 15340 CH 7/6/2001 ¢.1~79 ~-~ction Test FINAL 14053 15215 CH 7/6/2001 ~Dice~ctio nal Survey FINAL AVludiog ---~2---~-~ FhNAL 10182 FINAL ~.C;,¢~Array 2/5 FINAL Induction/DEN/NEU r..~ Array Induction/ 2/5 FINAL DEN/NEU ~..,aifpe r Log 2 FINAL End of Well Report FINAL orr Cased Hole 5 FINAL ation/RES ~:t~Caliper 2 FINAL ~d~rasonic Borehole 5 FINAL Imager ~o~ltrasonic Imaging Tool 5 FINAL ~ Ultrasonic 2/5 FINAL Borehole Imager ~.-Brpole Shear Sonic 5 FINAL ..~ip01e Sonic Imaging 5 FINAL oh 9/25/2001 874S 3212 8976 OH 7/6/2001 8800 13209 OH 7/6/2001 12900 14695 OH 7/6/2001 14356 15338 CH 7/6/2001 CH 7/6/2001 13800 14600 CH 7/6/2001 3212 8976 OH 7/6/2001 14360 15050 CH 7/6/2001 14126 15234 CH 7/6/2001 9019 13209 OH 7/6/2001 14356 15338 OH 7/6/2001 12900 14695 CH 7/6/2001 8998-15036, Digital Data 12770-14717, Digital Data 1-15340, Digital Data 14053-15215, Production Test Directional Survey -6746--f473, ~v~udiu~-'- ~AI ,~o-~ 3212-8976, Digital Data 8800-13209 BL, Sepia 12900-14695 BL, Sepia 14356-15338 BL, Sepia End of Well Report, Paper Copy 13800-14600 BL, Sepia 3212-8976 BL, Sepia 14360-15050 BL, Sepia 14126-15234 BL, Sepia 9019-13209 BL, Sepia 14356-15338 BL, Sepia 12900-14695 BL, Sepia DATA SUBMITTAL COMPLIANCE REPORT 7/2112003 Permit to Drill 2010310 Well Name/No. REDOUBT UNIT 2 Operator FOREST OIL CORP MD 15325 ~T~/.D 12601 Compl~at. 6/27/2001 ~' j" /~rray Induction/Dipole Shear S ,.~Gamma Ray ,~2;~Casing collar Iocator ~ Casing collar Iocator GR Gamma Ray GR Gamma Ray ~J~C Casing collar Iocator ~See Notes ~-"~ a t Formation Tester ~NEU n~duArray ction/Sonic DT ¢~ement Bond Tool embinable Magnetic 5 sonance . ,~J""Dipole Shear Sonic 5 _Dipole Shear Sonic 5 ear 'lnduction/Dipole 2/5 S N~E, Array Induction/ 215 ~Array Induction/ 2/5 NEU /T. EMP/Base and Post 5 Injection Completion Statu 1-OIL 2/5 FINAL 14356 5 BM 5 BM 5 BM 5 BM 5 BM 5 BM 5 BM APl No. 50-733-20501-00-00 Current Status 1-OIL UIC N 7/6/2001 7/6/2001 7/6/2001 7/6/2001 7/6/2001 7/6/2001 7/6/2001 716/2001 7/6/2001 7/6/2001 7/6/2001 7/6/2001 7/6/2001 7/6/2001 7/6/2001 7/6/2001 6/6/2002 6~6~2002 6/6/2002 6/6/2002 6/6/2002 6/6/2002 6/6/2002 15338 CH 12770 14717 Case 8998 15036 Case 1 15340 Case 3212 8976 Open FINAL 14424 15164 CH FINAL 236 3685 OH FINAL 12900 14695 OH FINAL 14126 15234 CH FINAL 14400 15200 CH FINAL 9019 13209 OH FINAL 3212 8976 CH FINAL 3212 8976 CH FINAL 3212 8976 OH FINAL 14356 15338 OH FINAL 100 9000 CH 1 14974 15210 Case 1 14974 15210 Case 1 14500 15265 Case 1 14500 15265 Case 1 14348 14656 Case 1 14348 14656 Case 1 13444 13880 Case 14356-15338 BL, Sepia ~ 12770-14717 ~ 8998-15036 79. 1-15340 ~ 3212-8976 14424-15164 BL, Sepia 236-3685 BL, Sepia 12900-14695 BL, Sepia 14126-15234 BL, Sepia 14400-15200 BL, Sepia 9019-13209 BL, Sepia 3212-8976 BL, Sepia 3212-8976 BL, Sepia 3212-8976 BL, Sepia 14356-15338 BL, Sepia 100-9000 BL, Sepia bridge setting plug PGGT bridge setting plug PGGT Perforation Record PGGT Perforation Record PGGT Perforation Record CPST Perforation Record CPST Correlation Log Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments Permit to Drill 2010310 DATA SUBMITTAL COMPLIANCE REPORT 712112003 Well Name/No. REDOUBT UNIT 2 Operator FOREST OIL CORP APl No. 50-733-20501-00-00 MD 15325 TVD 12601 Completion Dat 6/27/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION w~, co~? ~~. Chips Received? N Analysis Y / N R e.c~.ive, d ? Daily History Received? Formation Tops ~:~ / N Comments: Compliance Reviewed By: Date: Janua~ 10,2003 F O R E S T O 1 L C O R P O R A T I © N Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK, 99501 Attention: Commissioner Cammy Taylor Re: Redoubt Unit (RU) #2 well, ESP completion Dear Commissioner Taylor: Forest Oil recently completed Redoubt Unit #2 with a permanent ESP completion. The downhole Liquid Level Control Valve was run prior to the ESP. Attached is the 10-404 Report of Sundry Well Operations, detailing the work performed and the current condition of the well. Please call me if you or your staff have any questions. Thank You. RECEIVED JAN 10 2005 Alaska Oil & Gas Cons. Commissior~ Anchorage Paul D. White Drilling Manager- Alaska Division Forest Oil Corporation Attachments: 10-404 Report of Sundry Well Operations RU #2 Completion Schematic Daily Operations Summary STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS i". Operations performed: Operation shutdown Stimulate Plugging Perforate Pull Tubing Alter casing Repairwell Other X Run ESP Completion 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Forest Oil Corporation Development: 90' MSL 3. Address Exploratory: X 7. Unit or Property name 310 K Street, Suite 700 Stratigraphic: Redoubt Unit Anchorage, Alaska 99501 Service: 4. Location of well at surface 8. Well number 1918' FSL, 320' FEL, Sec. 14, T7N, R14W, SM Redoubt Unit #2 At top of productive interval 9. Permit numb, er / approval number 2415' FNL, 866' FWL, Sec. 19, T7N, R13W, SM 302-345 At effective depth 10. APl num~'er 2627' FNL, 1307' FWL, Sec. 19, TTN, R13W, SM 50-733-20501-00 At total depth 11. Field/Pool 2627' FNL, 1307' FWL, Sec. 19, TTN, R13W, SM Redoubt Shoal Field 12. Present well condition summary Total depth: , measured 15,325' Plugs (measured) true vertical 12,601' Retainer set at 15,218' MD Effective dePth: measured 15,218' Junk (measured) true vertical 12,516' Casing Length Size Cemented Measured depth True vertical depth Structural N/A N/A N/A N/A N/A Conductor 200' 36" Driven 200' 200' Surface 3,212' 13 3/8" Surf. 3,212' 2,918' Intermediate 9,011' 9 5/8" 1070 cuft 9,011' 7,534' Drilling Liner 5,561' 7 5/8" 193 cu ft 14,320' 11,746' Production Liner 1,213' 5 1/2" 274 cuft 15,325' 12,601' Perforation depth: (14,420'-14,542'), (14,550'-14,612'), (14,682'-14,788'), (14,782'-14,834'), (14,840'-14,942'), (14,948'-14,980'), (14,974'-14,996'), (15,002'-15,020'), (15,014'-15,130'), (15,136'-15,152'), (15,146'-15,192'), (15,228'-15,256') 3 3/8" 6 spf (MD) (11,826'-11,926'), (11,933'-11,984'), (12,043'-12,132'), (12,127'-12,171', (12,176'-12,263'), (12,269'~12,296'), (12,291'-12,310'), Tubing (size, grade, and measured depth) 3 1/2" tubing set at 13,796' MD (408 jts L-80 on bottom, 32jts P-110 on top) ' Packers and SSSV (type and measured depth) LLC-3 valve set in Baker model FA packer @ 14,015' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) A~as~:a 0i~ & Gas Cons. C0mr~issio~", Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classsification as: Well Schematic Oil X Gas Suspended Service Daily Report of Well Operations 17. I hereby c~~oing is true and correct to the best of my knowledge. Signed:~" Title: Drilling Manager, Forest Oil Corporation Date: Form 10-404 rev 06/15/88 -- SUBMIT IN DU ~LICATE RB[II S BFL Redoubt Unit repletion - November 2002 36" A 38 200 TVD 150 # Welded 200 MD 68 # BTC 32!2 MD 24 jts 3 1/2" L-80 Tnbing 3 1/2" L 80 PLop 384 its 3 1/2" L80 Tubing 3 1/2" L 80 Pup ESP Assernbly TO[ ('¢ 8759 MD 9 5/8" L 8(I7534 TVD 47# BTC 9011 MD Cenhif[l~ ESP Assef'~lbly (top of dischalge head) TOL @ 14112 MD Model FA Packel (9-) LBO 11746 TVD Hydli1521 14320 MD EZ Drill ~ 15218 MD 12601 ]VD Hydri1521 15325 MD OPERATIONS SUMMARY REPORT Today's Date: 01/09/2003 WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: REDOUBT UNIT #2 REDOUBT SHOAL 1 AFE NO: WELL ID NO.: APl NO.: EVENT DESC.: 025850 507332050100 50-733-20501-00 ESP Completion DATE: 11/12/2002 DSS: 1 DEPTH: 15,323 MUD WT: 8.70 CUM COST TO DATE: 50,456.68 HOURS PH O._~P 14.00 C BP 4.00 C PT 6.00 C RS DATE: 11/13/2002 ACT Nipple up riser, choke lines, BOP ect. Test BOP. Hydril failed. Change out Hydril packing element. ACTIVITY DESCRIPTION DSS: 2 DEPTH: 15,323 MUD WT: 8.70 CUM COST TO DATE: 105,680.18 HOURS PH O._~P 2.50 C PT 2.50 C BP 3.00 C WH 1.00 C CC 13.00 C TR 2.00 C PP ACT ACTIVITY DESCRIPTION TEST BOP'S. NIPPLE UP, BELL NIPPLE, FLOW LINE, TRIP TANK LINES & DRIP PAN. PULL TWO WAY CHECK. MONITOR WELL. STATIC. PULL TBG HANGER. WELL ON VACUUM. ClRC 21 BBL'S BEFORE GETTING RETURNS. APPR 50 BBLS CRUDE, 95 % KCL RETURNS @ 70 BBL PUMPED. WELL STATIC. TOH L/D 3 1/2" TBG. SET WEAR BUSHING. RIG UP SWS WIRELINE. DATE: 11/14/2002 DSS: 3 DEPTH: 15,323 MUD WT: 8.70 CUM COST TO DATE: 208,895.94 HOURS PH 1.00 C 2.50 C 6.50 C 1.00 C 4.0O C 1.00 C 2.5O C 4.50 C 1.00 C TR OP ACT ACTIVITY DESCRIPTION PP SET WEAR BUSHING. RIG UP SCHLUMBERGER. PP RUN SWS 6.60 GAUGE RING / JUNK BASKET T/14,130 (WLM) TAG 5 1/2" LINER TOP. PP M/U BAKER TYPE 1 PACKER, RUN & SET W/SWS WIRELINE. TOP OF PACKER SET @ 14,050. CORRELATE 7 5/8 L/T @ 8768 WLM. RS SERVICE RIG. REMOVE ESP SHEAVE RIGGING F/DERRICK. MONITOR@ .5 BPH LOSS. TR P/U SWS LLC-3, BAKER ANCHOR & RUNNING TOOL W/9K SHEAR. TIH T/8,820. RS CUT & SLIP DRLG LINE. TR TIH. @ 13,950 UP WT 310 K. DN WT 195 K ATTEMPT TO SET LLC. WORK UP T/35K OVER DN WT. UNABLE T/ OBTAIN ANY OVER PULL. TR TOH T/10,000'. DRILL STRING FLOWING BK. SHUT IN WELL,MONITOR CSG / DP PRES. NO INCREASE NOTED. OPEN WELL, FLOW INCREASE OUT OF DP. CIRC 9000 STKS. MONITOR. WELL STATIC. TOH DATE: 11/15/2002 DSS: 4 DEPTH: 15,323 MUD WT: 8.70 CUM COST TO DATE: 621,036.04 HOURS PH O._~P 4.00 C TR 20.00 C AL ACT ACTIVITY DESCRIPTION POH after setting LLC valve. Pick up ESP motor and seal sections. Assemble ESP units. Attach power cable. Dress ESP. DATE: 11/16/2002 DSS: 5 DEPTH: 15,323 MUD WT: 8.70 CUM COST TO DATE: 673,631.04 HOURS PH OP 24.00 C AL ACT ACTIVITY DESCRIPTION Run ESP completion with power cable. Depth 6500' at report time. DATE: 11/17/2002 DSS: 6 DEPTH: 15,323 MUD WT: 8.70 CUM COST TO DATE: 721,111.04 HOURS PH OP 24.00 C AL ACT ACTIVITY DESCRIPTION Run ESP pump. Check continuity. Attach cable. M/U tbg hgr at report time. DATE: 11/18/2002 DSS: 7 DEPTH: 15,323 MUD WT: 8.70 CUM COST TO DATE: 780,417.54 Page No: 1 Copyright © 1993 - 2002 by Epoch WellSite Services, Inc. All rights reserved. OPERATIONS SUMMARY REPORT Today's Date: 01/09/2003 WELL NAME: RIG NAME: FIELD NAME: EVENT NO.: REDOUBT UNIT #2 REDOUBT SHOAL 1 AFE NO: WELL ID NO.: APl NO.: EVENT DESC.: 025850 507332050100 50-733-20501-00 ESP Completion DATE: 11/18/2002 DSS: 7 DEPTH: 15,323 MUD WT: 8.70 CUM COST TO DATE: 780,417.54 HOURS PH O_..~P 0.50 C AL 2.00 C WH 5.5O C BP 2.00 C WH 2.00 C WH ACT ACTIVITY DESCRIPTION Make final splice at TBG Hgr. Land TBG with 90,000# string weight. Test seals. Nipple down BOP. Nipple up tree. Test tree flange and valves to 5000 psi. Skid rig. Relese rig. Page No: 2 Copyright © 1993 - 2002 by Epoch WellSite Services, Inc. All rights reserved. ORES T OIL C 0 R P 0 · ~' . R A T I N November 6, 2002 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: RU #2 Permanent Completion Dear Mr. Maunder, Forest Oil temporarily completed Redoubt Unit #2 in 2001. At that time, a string of 3 ½" tubing was left hanging in the well, with a plug in the tubing at 374' MD. The plan is to pull that completion, run the liquid level control valve stabbed into a packer and run the ESP completion. An outline procedure has been attached. If you have any questions, please contact me at 258-8600. Paul D. White Drilling Manager- Alaska Division Forest Oil Corporation Attachments: 10-403 Application for Sundry Approvals Outline Procedure Original Completion Schematic- RU #2 Planned Completion Schematic- RU #2 13 5/8" 5M BOP Schematic RECEIVED NOV o 6 2002 Alas~ 0il & Gas ~ons. commissior' Anchorag~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Install ESP Completion 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Forest Oil Corporation. Development: 90' MSL feet 3. Address Exploratory: X 7. Unit or Property name 310 K Street, Suite 700 Stratigraphic: Redoubt Unit Anchorage, Alaska 99501 / Service: 4. Location of well at surface t,/' ,./' ~ 8. Well number 1918' FSL, 320' FEL, Sec. 14, T07N, R14W, SM Redoubt Unit #2 At top of productive interval 9. Permit number 2415' FNL, 866' FWL, Sec. 19, T07N, R13W, SM 201-031 ~ At effective depth 10. APl number / 2627' FNL, 1307' FWL, Sec. 19, T07N, R13W, SM 50-733-20501-00 At total depth 11. Field/Pool Redoubt Shoal Oil Field 2627' FNL, 1307' FWL, Sec. 19, T07N, R13W, SM Redoubt Shoal 12. Present well condition summary Total depth: measured 15,325 ft "/-" Plugs (measured) true vertical 12,601 ft"-/' Retainer set @ 15,218' MD Effective depth: measured 15,218 ft Junk (measured) true vertical 12,516 ft Casing Length Size Cemented Measured depth True vertical depth Structural 200' 36" n/a 200' 200' Conductor Surface 3,212' 13 3/8" Surf. 3,212' 2,918' Intermediate 9,011' 9 5~8" 1070 cuft 9,011' 7,534' Drilling Liner 5,561' 7 5/8" 193 cuft 14,320' 11,746' Production Liner 1,213' 5 1/2" 274 cuft 15,325' 12,601' Perforation depth: (14,420'-14,542'), (14,550'-14,612'), (14,682'-14,788'), (14,782'-14,834'), (14,840'-14,942'), (14,948'-14,980'), (14,974'-14,996'), (15,002'-15,020'), (15,014'-15,130'), (15,136'-15,152'), (15,146'-15,192'), (15,228'-15,256') 3 3/8" 6 spf (MD) (11,826'-11,926'), (11,933'-11,984'), (12,043'-12,132'), (12,127'-12,171', (12,176'-12,263'), (12,269'-12,296'), (12,291'-12,310'), (12,315'-12,331'), (12,326'-12,427'), (12,432'-12,446'), (12,441'-12,482'), (12,514'-12,539') 3 3/8" 6 spf (TVD) Tubing (size, grade, and measured depth) 3 1/2" L-80 set @ 14,029' MD Packers and SSSV (type and measured depth) Otis "X" Nipple w/dual PX Plug set @ 374' MD 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 11/10/2002 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certifl~th~t the foregoing is true and correct to the best of my knowledge. Signed: ~~ Title: Drilling Manager, Forest Oil FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~O"~) ~)~ ~-~I~).-~-A.%-~ IApproval No. Plug integrity BOP Test_.~__ Location clearance__ _ REC~J~jr~r Mechanical Integrity Test ~ Subsequent form required 10- t'4L~L-,~. L: I V L NOV 0 6 2002 Alas~ Oil& Gas Cons. Commission Original Sigfl~d ~' Anchorage , / Approved by order of the Commissioner Commissioner Date Jl/~J./LJ(~-- Form 10-403 Rev 06/15/88 RBD~IS BFL N0!/ 15 2nno SUBMIT IN TRIPLICATE Redoubt Unit #2 - Permanent Completion Outline Summary 1. Move Rig to Leg 3, Slot #2 2. Nipple Down 3 1/8" production tree 3. Nipple up 13 5/8" 5M BOP stack. Test BOPs to 3,000 psi. 4. Pull 3" BPV. 5. Pull tubing hanger and 3 ½" tubing. L-80 pup on hanger will need to be changed out with P-! 10 pup. Send tubing to Tuboscope for inspection. 6. Set Baker Model "FA" packer on wireline at XXXXX ft. ~ \~,(3CC3t 7. RIH w/Schlumberger LLC-3 valve. Stab into packer. Pick-up, shear-off and release LLC valve. 8. RIH w/ESP motor and pump assembly. The pump will be run on 1,000 ft of 3 ½" P- 110 and the remainder will be 3 ½" L-80. 9. Set 3" BPV in tubing hanger. 10. Nipple down 13 5/8" BOPE 11. Nipple up 3 1/8" production tree 12. Pull BPV 13. Turn over well to production crew. TUBING HANG IR W/3" H BPV RU #2 TUBULAR DETAIL JUNE 27, 200i 56' KB 36" Piles 3 172' PUP JT. 200' MD, 200' TVD I0 JOINTS OF 3 1/2" TBG 13 3/8" 68#, L-80 BTC OTIS "X" NIPPLI,i W/ DUAL PX PLUG ,~t 374'KB 3212' MD, 2918' TVD 435 .IOINTS 3 1/2" TBG 9.3# 8rd, M()DIEI~ D CONN 8759' 7 5/8" LINER TOP 9 5/8" 47#, L-80 BTC 9011' MD, 7534' TVD 7-5/8" 29.7#, L-80 Hydril 521 3 1/?MULI SHOE(k,!4029'KB. 14112' "~ 5 1/2" I.INI R 14320' MD, 11,746' TVD TOP -- TOP SHOT (}~; 14420' 5-1/2" 17#, L-80 Hydril 521 15,325' MD, 12,60i' TVD RETAINER SIT (£~)15218' W,LM. VITCO (}RAY RliP. TI!STED PROD TREE BONE'T (HGR NICK S~ALS & RING GASKI:T) TO 5000 PSI, PROD TREli B()DY TO 5000 PSI BOTtt TEST ttELD FOR I5 MINS. RU #2 ESP Completion Plan FUBING tlANGER 56' KB 3 I/2' PUP 36" Piles 200' MD, 200' TVD 13 3/8" 68#, L-80 BTC 18 1/2" Hole 9 5/8" 47#, L-80 BTC 12 1/4" Hole 3212' MD, 2918' TVD 3 1/2" TBG 9.3# 8rd, MODIFIEI) CONN. [000¢ ¢- ! 10, 8759' 7 5/8" LI[Ntq~ \ 9011' MD, 7534' TVD I',SP Pt:rap 7-5/8" 29.7#, L-80 Hydril 521 8 1/2" Hole 14112' ~ 5 1/2" LiNeR 14320' MD, 11,746' TVD TOP -- TOP SHOT @ 14420' 5-1/2" 17#, L-80 Hydril 521 6 3/4" Hole 15,325' MD, 12,601' TVD ~TAINER SET (a:I5218' W.L.M. VETCO GRAY REP. T/ STI D PROD. TRIE BONET (}iGR NECK SEALS & RING GASKI F)TO 5000 PSI, PROD 'I'RI"~[' BODY TO 5000 PSI BOTH TIST HELl) FOR 15 MINS. Nabors Rig 429 13-5/8" 5000 psi BOP Stack Redoubt Unit #2 5000 psi Annular 5000 psi Blind Rams 5000 psi Pipe Rams 3" Kill Line 1 = HCR Valve 2 = Gate Valve Mud Cros: ~ 2 1 5000 psi Pipe Rams 3" Choke Line 13 5/8" 5M Wellhead 13-3/8" Surface Casing 9-5/8" Intermediate )rest Oil Corporation Alaska Division 310 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITI'AL To: Phone: Lisa Weepie/Howard Oakland AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 {907/ 279-1433 From: Date: Linda M. Starr Forest Oil Corporation 310 K Street, Suite 700 June 6, 2002 Anchorage, AK 99501 Phone: (907) 868 - 2162 FAX: (907) 258 - 8601 TRANSMITTAL DESCRIPTION: Redoubt Unit #2, AP1#50-733-20501-00 1 Icg Perforation Record/PGGT/CCL/G R 6/4/01 7 5" 15,265 14,500 _1/_o_ g_ .... _ _B?_d g_e_ _P i_ .ug_ _s_ e_t t i__~n g_/_ .P_G_ _G. T/CCL/_G__R_ 6~ .J_u_n_-.2_ .0_ _0__1' ...................... _6/_6/_01 .......... _7_ .......... 5~"_ ........................ _1_5,_2_ 1~0 .................. __1_4:,.9_7__4- ....... _1__ I_o_g_ ....... _c_.p_s_T_B_r.!_d_ge_._p!u_g__S__e.t_tj._n_.g/G R/_C_C/1__2_:-_,:!..U_[1_-.2_0..._0_!__ ...... _9.6_/._11/___2_0.O_1_ ........ _8. .............. __5_"~ .............. 1_ _4?_§_5_6_ .................. .!_-4_,.3_.`4.8__ 1 10g- Correlation Loq. 06/13/2001 10 5" 13,880 13,444 .__l_fi_l m ..... P _e_d_o_ r_a_t i_o_n_B_e_c p_r..d_/.P_ __G _G_T_/_ _C__C L/G__R___ .............................. 6/__4_/.0_1.. .......... _7_ ............. _5.1'_ ....................... 15,2_6_5_ .................. 14_,_5_00__ ......... _l_f_il_.m .... _B ri.dQ e..P_ I_u_g_ .S__ .e.t_ t_!_ng_/. _P_G...G..T_/_o_o__~_~_R 6_-_J_u_..n__-_2_..0. 0_1- ...................... 6/_.6_/0!. ............ .7__ ............ __5"~ ............................... _1_5_2__1_ 0- .................. _1..__4_,_9_7_.4_ .... ..... ]_fiLm ...... ~.P--S-T..-Br-!~d-g.~e~-~!.~u-g-Se-tt-in-g~-G-R~--C--C-L-1~2-~-J~u~.n...:-2-~.~-1 ........ _0_61~1.1__1_2_ 0_ 0__1. ......... 8 ............ _5.['. ............................. !_4__,_6_5_ _6_ ....................... .1..-4.._3_4_.-8 1 film Correlation Log_ ..................................................... _0.6/131______2091 ....... _1._0_ ........... _5_" .................... _1_3,_8_8_0_ ............. __1_3.,_4_4_4- (Dig_ital data wasn't available for these Ioqs) Box 1 of 6 74 Baggies ...... .C]_o_r_e__C_.h.!?s/..e..n__d_c!i_p__p.[n_g_s ..... _R.e__d__o_u_bt_U_n_it ~2 ........................ ~pB~B3~ ......... ~p:~ ........... 2 of 6 96 ....B__ag~oies Core Chips/end clippings Redoubt Unit #2 14632.7' 14505.3' ...... _3_o_[.6_ ................ _8.__5_ ....... _B_a..g_gi_e__s_. c___o_r_e_e C__)h!p_s/_end_ clipping_s Redoubt Unit #2 14849.3' 14633.7' 4 of 6 72 Bag. gies Core Chips/end cl!.p_p_i_n..g_s Redoubt Unit #2 14948.3' 14850.3' ..... 5_.9_f_-6.- .............. 7_4 ...... .B_.a_g..g_ies Core Chips/end clippings_ ....... __R__edoub_t_...U..n_it_#_.2_ ................................ 1_50_3__2._3'__ ......... _1__47_49__:.3__~_' ..... 6 of 6 45 Bag_g]es Core Chips/end clippings Redoubt Unit #2 15086.3' 15033.3' Please sign below to ackno~vledge receipt. Received B, Date: IReturned to Forest Oil Accepted By: d Ji4 0 6 2002 & Gas Cons. Commission Anch0m. ge RU2.xls, Page I of 1 , {" 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 100 Phone: Anchorage, AK 99501 (907) 279-1433 From: Date: Linda M. Starr Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Phone: (907) 868 - 2162 FAX: (907) 258 - 8601 June 6,2002 TRANSMITTAL DESCRIPTION: Well Redoubt Unit #3, AP1#50-733-20504-00 .B_o__x_l_.pf___3_ ......... Cuttin_gs Samples 144 Vials 11,720 7,400 Box 2 of 3 Cuttin_g....s_ Samples 144 Vials 16,010 11,720 Box 3 of 3 Cuttings Samples 31 Vials 16,940 16,010 Please sign below to acknowledge receipt. RU3.xls/Pagel 6-5-02 d~jl,,l 0 (; ~.00:2 Anchora.~e Date Modified:06/06/2002 Date Prepared: 12/6/00, bk RES T O I L C O R P O R A T c~ct),,../,,.,,,,~/,,. ~c' t~,.;/,, I 0 N August 3,2001 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 #2 Enclosed is Forest Oil's Well Completion Report and Log for the Redoubt Unit #2 well, drilled from the Osprey Platform. Redoubt Unit #2 was Drill Stem Tested in the Hemlock formation and was completed with 3 '/2" tubing. A permanent completion with artificial lift will be installed in the summer of 2002. If there are any questions, please contact me at 258-8600. Drilling Manager- Alaska Division Forest Oil Corporation RECEIVED AUG 0 3 Alaska Oil & Gas Cons. Commission Anchorage Attachments: Well Completion Report (form 10-407) Redoubt Unit #2 Well Schematic Well Test Chronology Daily Operations Summary Final Directional Survey ORIGINAL WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: × GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Forest Oil Corporation 201-031 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1918' FSL, 320' FEL, Section 14, T07N, R14W, SM At Top Producing Interval 2415' FNL, 866' FWL, Section 19, T07N, R13W, SM At Total Depth 2627' FNL, 1307' FWL, Section 19, T07N, R13W, SM 8. APl Number 50-733-20501-00 9. Unit or Lease Name Redoubt Unit 10. Well Number No. 2 11. Field and Pool Redoubt Shoal Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 90 KB I ADL 381203, ADL 374002 12. Date Spudded2/24/01 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °fish°re I 16' N°' °f C°mpleti°ns5/18/01 6/27/01 n/a feet MSL 1 115,325' M:D / 12,601' TVD 15~218' MD / 12,516' TVD Yes: x No: Otis X Plu~l ~ 373' MD n/a 22. Type Electric or Other Logs Run Quad Combo, UBI, CMR, USIT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2(7' 133~ driven n/a None 13 3/8" 68~ 17 1/2" 5821 cuff None 9 5/E' 47# 7 5~" 29.7 # 5.1/2, 17 # 24. Perforations open to Production interval, size and number) GRADE K-55 Surf. L-80 Surf. L-80 Surf. L-80 8~759' L-80 14~112' (MD+TVD of Top and Bottom and SETTING DEPTH MD TOP BOTTOM 200' 3~212' 9,011' 14,320' 15,325' 14,420'MD (11,826'TVD)-14,542'MD (11,926'TVD), 14,550'MD (11,933"I'VD)- 4,617_'MD= (11,984q'VD), 14,682'MD (12,043'TVD)-14,788'MD (12,132q'VD), '~4,782,MD (12,127'TVD)-14,834'MD (12,171'TVD), 14,840'MD (12,176'TVD)- 4,942'MD (12,263"1'VD), 14,948'MD (12,269'TVD)-14,980'MD (12,296'TVD), 14,974'MD (12,291'TVD)-14,996'MD (12,310'TVD), 15,002'MD (12,315'TVD)- 1~ 5,020'MD, (12,331 "rVD), 15,014'MD (12,326'TVD)- 15,130'MD (12,427'TVD), 't 5,136'MD. (12,432'TVD)-15,152'MD (12,446'TVD), 15,146'MD (12,441 'TVD)- 5,192'MD (12,482'TVD), 15,228'MD (12,514'TVD)- 15,256'MD (12,539'TVD) 33/8" 6 spf 12 1/4" 1070 cuff None 8 1/2" 193 cuff None 274 cuff None TUBING RECORD 6 3/4" 25. SIZE DEPTH SET (MD) PACKER SET (MD) 31/2" 14~029' n/a 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. AMOUNT & KIND OF MATERIAL USED DEPTH INTERVAL (MD) n/a hUG ZOO! Date First Production n/a Date of Test Flow Tubing Press. Hours Tested Casing Pressure PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) Drill Stem Test Details in Attachment PRODUCTION FOR TEST PERIOD => CALCULATED 24-HOUR RATE => OIL-BBL OIL-BBL GAS-MCF GAS-MCF WATER-BBL WATER-BBL Anchorage CHOKE SIZE I GAS-OIL RATIO I 01L GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Corn from, the RU ~2 well displayed interbedded fine to medium grained sandstones, and pebble conglomerates with minor claystones, siltstones and coals. Much of the core was oil'saturated. Apparent structural dip from the core after orientation rankled from 5-30 de~lrees in an east to southeast direction. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE (p I~' Submit in duplicate ORIGIh AL GEOLOGIC MARKERS FORMATION TESTS ,, NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH SS'I'VD GOR, and time of each phase. Hemlock Bench I 14,365' 11,692' Drill stem test #1 and ~2 were performed on the Hemlock formation. The Well test chronology Hemlock Bench 2 14,417' 11,734' and data is attached separately. Hemlock Bench 3 14,519' 11,817' Hemlock Bench 4 14,912' 12,148' Hemlock Bench 5 15,100' 12,31 (7 Hemlock Bench 6 15,137' 12,343' West Forelands 15,183' 12,384' 3.1;. UST OF ATTACHMENTS Welll Schematic, Well Test Chronology, Daily Operations Summary, Final Directional Survey 32. I' hereby cer~l~at the foregoing is true and correct to the best of my knowledge Signed Title ~Drilling Manager Date ~/'~/(~. / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classifmation of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form, 10-407 ORIGINAL TUBING HANGER W/3" H BPV RU #2 TUBULAR DETAIL JUNE 27, 2001 56' KB 36" Piles 3 1/2' PUP JT. 200' MD, 200' ]'VD 10 JOINTS OF 3 1/2" TBG 13 3/8" 68#, L-80 BTC 17 1/2" Hole 9 5/8" 47#, L-80 BTC 12 1/4" Hole OTIS "X" NIPPLE W/ DUAL PX PLUG ~ 374'KB 3212' MD, 2918' TVD 435 JOINTS 3 1/2" TBG 9.3# 8rd, MODIFIED CONN. 8759' 7 5/8" LINER TOP 9011' MD, 7534' TVD 7-5/8" 29.7#, L-80 Hydril 521 8 1/2" Hole 3 1/2" MULE SHOE ~14029'KB. 14112' ~ 5 1/2" LINER 14320' MD, 11,746' -I'VD TOP TOP SHOT ~ 14420' 5-1/2" 17#, L-80 Hydril 521 6 3/4" Hole 15,325' MD, 12,601' TVD RETAINER SET @~.521s' W.L.M. VETCO GRAY REP. TESTED PROD. TREE BONET (HGR NECK SEALS & RING GASKET) TO 5000 PSI, PROD TREE BODY TO 5000 PSI BOTH TEST HELD FOR 15 M1NS. PRODUCT ON TEST NG SERVICES ' IWELL RU#2 DATE 5130/01' I cnck ICu, I I coke I Tub r...3 Tub ~g $ a..'ic Dill Mete Gas Cum Me .... d Calm Inc Oil Cum M ...... d Ca.c!nc. : ~,,1, I T, I ~.:~- Io .....:s s~.e Pe. Tenp Pres P .... Temp O~,*c,; Rat,, Gas GOR I ildVol a.~. ..1e I,,,~d,~'wl hh:mm J hr I I ir, Psi(l-I) I F I P'~¢,~) l i"°fh201 F I :n IMMCFIDI M~SCF I~F~BLIbbl I 5/30101 1~.00:000 Ndve on O~p~uy PlalloHn bugiu rig up ' 0 0 0 0 0 0 19.00:006 boat on Iccnlicn. begia spotting equipt. 23:30.0010.5 (h~,continue Hg up till AM 5/31101 6'00:00 17 're~ume ~ig up 611101 0:00:00 35 Coll[uluu lig lip 6/2/01 3.00.00 62 Tubing pmled ~itj do~ 612/0l 12.00 0071 Left Osprcyplatfu~[, 617]01 8:30'00 187 5 ~live oll ~pley owef H~ln'.,p ~ ~',..I Te~t 611101 ' .~ ',¢ ;::~ 192 5 OII load buat b-9ia H9 up 617101 / ~ :~] :;) 207 Finish li~ up and salely 5yk, m Ir. si 6!~i0~ j :;u :~:~ 203.1333 Pimkel sut ~ ;:~ ~ ;~ 206 P[esstue le~4,d s(~p,tla[Ol lira: h~,d~l lu 1000 psi 1,4d lu~ 5 iGin 210 ~11~{~{1111~ lesled inlel m4nilold Io 5 k hchl tol 5 m n / c:; :~1 210 Plessule lest(~d salely wllve to 5k 1,4d 5 mlnu,:15 / ": :iu 210 25 Snlely Ineetin9 w/all pelsonnell ~ i::; .:u 212 ~omplete lla~e line pil and S~l)a~ato~ bbwdown ~ iL :hi 212.25 begin i~umping N2 dow~ h;bing ; I ~': :;o 214.25 N2 supply d~plek~d. 1735 ps~ II ¢',:;~ 214.4167 0 1735 I I .,; ;:O 214.5 o[~c, ii h:~h~l valw~ ii 214.516/ 0 1750 1: 'L :::: 21475 0 1930 I/ 3 2~5 1667 ;open w~ll tl,u adj choke 10/64 I.' '~. ~:] 215.25 1950 1'~ ~:1 ;:~' 215 3333 1840 i.: .' · :::i 215.416/ iltlj, t:lmkr~ opened Io 14 1755 i:- ,!; ~i;I 215 5 1650 '¢ .,)~g 215.55 chuku tu 16~64 ~.- ~ i:!) 215.7 chuke Io 18164 I ' ~::c:] 21575 ' 1285. I ~ ¢~ i::] 215.8 .chuk~ to 48164 17 57 {::]. 215.8667 'choku to 26164 I ~ ~)7 (;J 216.0333'choke Io 32164 I ) '5 ~:;~ 216.25. t; ~:! ;::] 216 5 .ttlbifto I)fessule less thaf~ 50 psi ~ !4:8 ;~ 217.51slight bubble ~ ~ ' ' ', ;~;]: 218.25 I Slight bubble , ~ "..,~ g.J ~ 218.5 Slight bubble { ~ : · .:'J :::] ~ 219 Slight bubble ~ ' ~ ~: ~ .; ~-a i 219.7167 I Fluids to sudace ~ 0 0 0 0 0 0 165 21 74 1.5 0.262 0.005 165 1 70 0 186 0 006 135 2 76 0 206 0.008 100 2 100 0.203 0 014 o! o'~ oi o oi o! ~ i: 4 ¢ :-.-]i 219.751 --;; :;o :::]i220 ! : --- ¥:, ,;t) j 220.0833 Start injecting anti foam __ ,):]] 220.5 i 32 i · ,, .'.::; o:] i 221] i 32l 30) 54; · :~ c.; ~:J 221 I API gravity 25.4 ! ~ i --~ '~: .:~.: t~:J; 221.5! ! 32! 15i 57 I" i:;: !~i]; 222 j ] 32 i 30 571 lq ~:: i;(]! 222.5) ', 32) 35) 54; 2231 i 32i 351 54i __7i) (:: i:~)!223.5 i 32i 25; 53 .'-:: '.;u; 224.5 J 32! 35! 53i ~ i 32i 35: 53 .- · ,.:.; '.:3 ! 225 ] ~ 32 ! 30 53 ~ --:-,- ;:~ C:~ 225.51 T 32; 30, 53: ___:-? 4:: cq: 225.6667 tOpen choke to 64/64 ?.; i': t:ni 225.751 Bypass inlet choke ~;t]' 226j i 128'. 10 64; ~:, ~:: ;:~) ] 226.5! f 128! ~7- 51 : t; ;);) :;J ~ 227 i r: :3 ;::) i 227.5 ! · '~) :::) ) 228.5 ) ? ~: :11 229.5 J ~ :~;; ;;:l ! 2301 -- · ~:~ :~i 230.5! 4 :~,i: :1 2311 4 ~,) :::11 231.5i · , ;--;i ;;:~ ' 2321 __ :. J'; ~U~ 232.5! ~ ;~;} t'-'~l ~2331 0.4 ! 0.4 '; 33.9; 0.4; i ' ] O[ 141.6i ' ' 6.3l 5.91 141.6: 6.3i Oi 01 O! i - 6.51 2~ 52.6! 8.5; 0.018 0.432~ 0.0161 0.6] ~2.~i 8:5! ~4.6; 17_51 91 216! 17.5i0.024 21.6] 4.1 98.4i 21.6 0.0241 47.71 26.1; 626.4! 47.7~ 0.024 60_71 13i 3121 60_7 0.024 o.o18i 0.00610.134i0.024! 0.1i 0 0.011 0.024i OI 98.4, 21.6, 273[ 0; 0; 0.024j ~ ~26.4i 47.7~; 26.~i ' Oi 0~ 0.024i O! 312: 60~i 27.f! : 1281 15, 52! ~ 128{ 15{ 521 1281 10l 54: 1281 10i 54! 128{ 10! 55i 128J 10i 55: 1281 51 54! i 128i 31 54: i 128i 251 55i 128) 15; 55! 1281 25i 57! 128i 10: 56! i 128i 10~ 55~ 80.5[ 19.6:47512; 80.510.024! 01 0 0.024? -0' 475.2! 80.~i 27.7? 97.2[ 16.7i400.8 :, 97.2 0.0241 O] 114.11 16.9!405.6;114.1 0.19310.169/ 4.050 0.193~ 1 405.6~ ! i i : [ , i , ' 278 133.91 19.8:475.2 i 133.910.193 0 ~4s.5[ l~.S':=7s.4J 14~s, 0.~3~ o[ o, 0.~ 0[- ~7s.4; h~S.s] 27.~! [ :: ~ ~ [ ~ --, m~.9~ 24.4~ sss.s~ ~s9.9] 0.1~3~ 183.5; 13.61 326.4i 183.5 J 0.193~ OI Ol 0.1g~t Ol 326.4: PRODUCTION TESTING SERVICES ~ ~ : ~ , WELL RUle2 DATE 5r30101 ~ ' i , --- c,,.,,~k c ..... ----F'Cboke T,,b~,',, 'r,,b,.0-1-"~'.",, I ~'* I "'l"t~'-"lI ~'"'-I C ..... I '1" ...... ,Ic,,;e.,,,.,1 ~, c..,,, . ..... ,~ c.,,c~ .... ::~o c.,,m I:W,,,!~ F~.~d c.m. I ..I Dale Time 'time ICOnlrnents/ S;zu JPres Temp !Pes Res Tenp ! 0 ce I Rae J Gus I GOR I fldVo Oi Gain I Rate Oil H20volH20Gain ;;Ratb::J; H2O ] Cut Rate FluidAPl J Mud Salinity~ pH iSolids F ! psi(q) I n ,f 1,20 I F / n I MMCF/DI MMCF ] SCFiBBL bhl hU J bbFdJ bblI bbl bhl ;~cI j: bbl ] % I bb[/d bbl APl IWelflhtl~linltvl 1% .... ~'d6"wl. ~,h:l,,t,6:30:00.1 h,~.5L_ / i. 128! ~i(g~01 '-- 55 ' ', ~ - i 7:0000 234 128 10. 55 1922 8.7' 2088 192.2 0.28 0.087 2.088'.0.28! 1I 208.8!192.2 J 27.3, 7:t2.00234.2 Silut m dow~dml, valw~. ~ f - ' i 7:30.00234 5 No mo.~ flow at suHace. 7 50 00 234.8333 Shut iu ESD valw 8:00:00 235 0: . 6110/01 2:55.00 253 9167 Bleed (Jo~l plessure above do'~dmle vdlv,: 2'56:00 253.9333 Choke lull open 3:00.00 254 Dowullolo valve open 3:05:00 254 0833 '.zero I)'abhh~ 3:08'00 254 1333 shghl bubble 4:00:00 255 'shuhl bubble. 5:00.00 256 :buhhle, no fluid 5:02:00 256.0333 :lhud to s.i [;H:,~ 5'30:00 256.5 no Iluid la SLU!aCe 5:35:00 256.5833;fluid to.,,mface 5:45:00 256.75 8 56 6!10!01 6'00'00 257 12 56 6.30.00 257.5 20 56 6:45:00 257.?5 25 56 7.00.00 258 14 56 7'05'00 258 0833 Wuehne RIH 8:00'00 259 9.00.00 260'no fluid lo suliace 10:00:00 261 Wuehnu GIH 0 57 11.00.00 262 Clu~u DIH uu,ni vdlvu 0 59 12:00:00 263 W~rehne POOH 0 59 12:30 00263.5 Wileline OOH. SIW ~ maldlold,d(j dowJi wi;lelJne 14:21.00 265.35 Stall well k~ll opoI1 well' 100 64 14:55.00 265.9167 Fluid Io SUIIHCL' 46 59 15'00 00 266 'Plllllp]l]0 Ihlld'; (fow[I ;lll[lll[ll,;. Illl;Jl]ll~ !0 IIl(:;ISlll(~ 16 35 O0 267 5833 Shut iu w,:ll, d9 down Ill;mifold and flowline, pJep,-Jle Io pull pipm 10:40.00 267'.66871209.04 bbl:~ Ilowed lo lu[Iks duung kdl 16.40 O0 26/.888/':'10t~d lullk bbls mcludJ.~l llu~h 467.5 Jppul Hemlo,, W..:~ Test 6/13/01 ,,.; ,u ,:3 ?1; ', Begin rig tip ;-: :~, ::;I :~': !', :lig t,p (:(uuphd(.', I)[:9in pII 6!14i01 :s ,(; :~a ;{ / ', pil sop inlet Ia 1000 p~;i, all linr:s good ! /', ,'!;I ~.'.~; 4 H=; ;pil choke manifold Io 4000 I 1', !~;I ~4~: :', isafely ineut[n9 WIth all I[Ivolved pcfsocnell / :;.J O~l :~4:j ,bogie pumping N2 to 1900 psi { ?, ';'j -~:: ';:N2 ptuoldn9 CO[lll)lete % :: ~ ;);I .~.,; ;1:. 'Bal dlOpped, gulls IIIgd · ::)/:::l ?:; 'li,J 1915 ', :]~ ;:;I ~':,' ~ ~ ~ 1935 ~': ;.U 1950 ', 1:~{::1 '-'./ J!J,/ 1970 !, 1 I '. ;J :',.- ;~ eJ 2000 I .'- ,.;g ,'..; 2~: L / 2059' · I': ~;() .;';.) ?'~ 2080 ii~,a:.' ;~:'--,: 2120: 5 tU g0 .:./ .:,Il,/ 2150 L .-': 00 ,'.,,7 -~:, 2180. .;'2, (-:-'-'~ d'..; I t:.i 2235 :./(L;) .;~./a.: 2260 :: .-':, :::1 ?:/:~:: ~ 2285 il ;;;1 ?-/ r"Jl,/ 2305 ': ~ "- ;::1 --: :" '4 2325 ~::(:~1 %; ::F:~ 2343 ', ::: ~:;J ~ , ' '-'; ~ [ upon well tu sop. choke ;:il 16164 ', '--" ~;~] , ..; i,'~,i 16 2362' ', 4:~ ~;~1 ¢,- ~:~,'.; 16 2250 :: ¢:.3 '~,.. ~'t ~; operl choke Io 20/64 ., .::: (:.) ~-,., ,4:; pldte ill Sulvice i; ( 2 ::1 .' ; 20 1390 56 '-- '[¥ ~J ~ .-~ '; 20 545 54 .:~2 i~;i [)Jl('ll ¢.lluku tu 24184 i [2:; 09 ~-=.*- 24 120 55 ~ ~; 'JU j24 %.(. set choke on lilm heater Io 32/64. open bypass on inlel maniiold i ~:! :2:! :',J , rio f]lJid t(J R[JIl,~l[:e, slighl I)tJIJi)h? :, l::: (;~., -'- Nt) Ihllll, '.llijhl hlliddl{. % t:~ ~:~ :~.': 7'.':-FJuJd to .~LIII;4Ce. 315 13 72 2.125 1.935 6 101 203 1 i0.9 261 6 203.1 0 497 0.217 5.208,0.497: 1~6 ~ 2o3.1 203.1 0 0 203 1.0.497 0 O: 0.497 i 0 0i 203.1] , ~ i ! i ? ' ;' 211.36 826 205.1 211 4 0.513 0016 0.397 0.513i 0.2~ 205.076i 211.362 232.2 2 47 59.3.232 2 0.549 0 0; 0.549i 059.28i232.2', ' 10.32 123 8 242 5 14 04 337 256 6, 242.52 0.561 256.56 0.575 269.36. 12 8 307.2 269.4' 0.575 J 0.012 0.144: 0.561i 0.1; ~-23.84~. 0014 0.336~ 0.575i '0.1~ 336.96i 0:~ 0.575! ....307.21 - i -' ? P _--- '. :, . i . . .... _ ~ . ~ J ' ' 0, 0.5751 0; -'- 0i -269.36 0 269.4 0~ -0.575 IPRODUCTION TESTING SERVICES J¢~LL RU#2 DATE 5!30101 : . ~'~" , Cock JC ..... Coke I Ttbn9 lui'.ing $,ahc ]'--~f, ,,let,.~ Gus C ..... M ...... d Calc. lnc ~1 Cum M ..... d Calcl ~0::, ~m, Wat~ ~ Flu,d ~m. I 0,, I ~me I Ti e lC ....... tslSze Pr~ I ~" , IP,.~ ] R,sJ Tenp I O Ice ] Rate J Gas I GOR } IldVol J ~lGain Rate ~1 H20vol Iffi0Gain R~e. ~nb'd~'wl hh:mml ~ I ',, =re(g)[ F mpsi(g) linofm20] F m = ]MMCFtDI MMCF ISCF/BBLI btdI h~ I bbl/d bbl bbl --- 8:30.00 -' 355.5 32 4~ · ~ J I ) I ) ~ r 9:00:00 356 32 30 33.9 33.9 1084.8 303.3 0396 0.396 12.672; 0.971~) 1084~8~ 30326 2655~ ) 25000~ 0.1 9:15.00 356.25 inlet .'~amph~ 2.0% wlc 9:30:00 356 5 inlel sample 25.0% w/c 9:45:00 356.75.inlel sample 15.0~/.. wit 10.00 00 357 32 35 10'30:00 351.5 'inlet ,..ample 6.0% 10:45.00 357 75 ..inlel sample 3.5 11:00:00 358 32 50 11:15.00 358.25 inlel ,';amph: 1.1"/,w/c 11'30 00 358.5 qnlet sample 0.5% wit 11:45 00 358.75 !inlel sample 0./5¥.. w/t; 12:00 00 359 32' 25 56 12:03:00 359.05 '.2' ch¢]ke fu!l open 12.15 00 359.25 !inlet sample, t. Jce H20 12'30 00 359.5'.inlet sample, trace H20 12:45.00 359.75 ,inlet .~ample, h~lcu H20 13'00'00 360: : 128 20 56 13.15 O0 360.25 !inlet sample 0.20% wlc 13:30.00 360 5 l inh~t sample 0.20% wit 13:45:00 5 :inlet :~amj)ht 0.20% w/c 14.00.00 I 128 17 56 14'15:00 3 inlet Sill~Jlle 0.1% 14:30'00 3 'Inlet Stilnple 0.1% 14:45.00 5 :inlet sample, ha~u H20 15:00:00 2 128 19 56 15:15:00 ~ inlet sufnp!e 0.1 15'30.00 - 5 inlet sample 0.1 15:45'00 3 inlet safnple. I[a~r~ t120 16:00.00 3 19 56 16.15.00 3.inlel sample O. 1% wit 16.30.00 5 :inlet sample, hilce H20 16:45:00 5 'inlet sample. If;ice HZ0 17.00.00 f' 18 57 17'30'00 ' 5 'mlel safnplc. If a~e 1t20 17:45:00 ' 5 inlet s~mq~l~, h,icl~ H20 18.00.00 5 15 57 18:15:00 3 inlet saml~h:, Irac~e t120 18.30.00 T ?del ~,3mple, Irace H20 18:45'00 ~ inlel .ample. hace H20 19:00:00 ~ 16 57 19'00'00 ~ do.hole valw clos(~d 19.10.00 ~ 0 psi al smlace, monilo~ fo~ 30 minnies 19:22:00 ~ shut in 19:23'00 ~ 'shul m al ESD valve. 6115~01 9 00 00 ) S:Hfacl~ ~,hul in i).~ssu~e 140 psi 9:02:00 ~ Cycle Hahbudon VillVU ojlell 9 05.00 ~ 140 9:15.00' 5 ~dight t~ubhl[, in bnck[~l 9:30:00 5 S~ghl bubble 5 57 9:33.00 ) Fluids tu 9.45.00 5 Inlel ~;ampht 0% h2(~ 10:00'00 I Inlol sample 0% h2o 38 58 10:00:00 I ~1 30 ~ 80 F 10.15.00 5 Inlet Sdmple 0% 10:30:00 5.inlel sample 0% h20 21 57 10.45:00 5 Inlel sample 10% h2o 11:00.00 ~ Inlol sample 0% h2o 11.00.00 ~ :~1 29 ~ 83 F 11 '15 00 5 :lnlel sampl~ I 1:30'00 - 5.1nlel ~;mnple 0% h2o 11:45:00 5 Inlel sample 0% h2o 12.00.00' ~ Inlol s~lml)le 0% h?o 12.00.00 ~ 'APl 29.5 ~ 83 12.15.00 5 ,hflul ~ample .3% h2n 12'30 00 5 ~ Inlel sample 0% h2o 12:45 00 ~ 'hdul sample 0'~, h2o 13 00 00' )'lnlel sample 0% h2. 16 57 13'0000 ' )iAPI29.25~ /SF 13:15.00' ~ :Inlet sample 0 X, h2o 13.30 00 ' ) lhdot sample 0% h2o 15 57 13.30.00 - )'~1 29 25 17.30.00 ) E linu OOH, ~i~ud duw~ 1'1:38:00' : ~'LPRN vnlw cwled open 62.59 28.69 688.6 331 9 4 116 3 72 8~ ' 4.691j 9561 33.02 792.5 365 5.856 1.74 41.76:6:431; ', I 131.11 355 852 400.5. 607. 0.214 5.136i6.645j., 0.6 8~2! 400.47i26.4~', 162.91 31.8 763 2:432.3. 6.12~ O.05j, 1.2~ 6.695 ~ 0.~ 76~.2; 4~2.27 [ 26~9; 195.95 33.04 793~ 465.3i 230.64 3469' 832.6: 500~ 6.21 0.03, 0.72~ 6.785~ 0.1~ 832.561 5~ 27~ . 264.51 33.87 812.9~533.9 ~6.24 0.03~ 0.72 6.815 0.1~ 812.88~ 533.87 ~ ~7.2~ 361.56 33.04 793~ 630.9] 6.3~ 0 365.06'35 229.1:634.4 ~ 6.3~ 0i 3e5.06 0 0: 6~.41 6.3i 0~ 0r 6.875 0~ ~T ~3~4~ 28.6~ ~ ~8.~ 41326 48.2 1217 7~682.6 ~ 7.475~1.175 425.29 12.03577.4T 694.6~7.475~ 0~ 0: 8.05'~'~ ~77.447 ~.~5~ 27.4~ 458.82 33 53 804.7~728.2~7.475~ 0~ 0~ 8.05~ 0~ 804.72~ 728,18; 27.9: 489.49'30.67 736.~ 758.8~7.705~ 0.23 5.52; 8.28~ 0.7~736.08 j 758.85; 28:~ 506.79 17.3 830.4~776.1~7.705~ ~ 0~, 8.28~ 0~ 830.4: 776.15J 28.3 PRODUCTION TESTING SERVICES ' i : i .... DATE' ' · '. '~/3om'1. - ...... ! ....... i ,. '"'"" -".-..., ~...'..'...l...Ch'o,~.:l T.~[ng:'I TUUng....:I. S~aUC .... C~,' .. ~""'"'1' ~"' I c ..... l- I. ...... al c~,~.,n~I ~, I ~'" IM ...... d ca~cm~I :mo:l: ~m I water F~id I ~m. - : .... ~mme"~l' :'a~e:.' t' :-~"".'t. '.T"~"'I""~'"I. 'n~ '1' ·Temp· ;1: '~" I R.t. I e., / GOR I ~dV.~ ~e.i,,Rate ~1 HZovol ~O:~i~t:::Rat~: I ~o I ~ t ~t. I ~,id ~ M.d ~i~ pH ~lids ;/:,"/'~v! I ', i.. · 'l:..'".in ..... I.~i(g).l. .F'.'.'t''psi(g)..l'.inofh20'l F. I ...in:" IMMCF/DI MMCF /SCF/BBLI bb~I t,N bbUd I bblI bblI ~::::l::::~d:l :bi 1% I b~d I ~ I~llWef"ht?aiiniM 1% i :. ~,', :::~ .~;'~ 9¢ .SITP 38 psig. Open ~oke to 128/64 adj. chok~.- ..... ' I:. ~.' :::i ~ '~/~d to su~ace. ~ ; ............... i 128~ 38; 57:. ~ -- 529.48 2269 99 798.8 7.705 0: 0~ 8.28: 0~ I .i 03 03 ~, ~ ~,i APl 29.6 (~'60 F. . '- · .-i~ 8:! ;;] %,1 'J=)__ _. ':128i 2-0-i ..... 57: ....... .:i: i.,,.i (:;] ~ I n,~ APl 2_9_(j~ 73 F i ,-i o~J~'..Z ~-~;) 1281 191 57' ,-: 7! :%1 ~./~! APl 29.2_@173 F · i . .:.' ~:~ c(! ".~,,:! 128" 19: 57: ..... .-/....;i ~:J ';'-'~ ~-".' APl 29_(~ 7~Z F ! ........... .-', 3;~ ..':~) ~':~ e~ ---- 1281 25: 56 > { :]~ ;':~ '--',4 9U 7~PI 29~1~ ~4 ¢ ~ ~' ' _ ..... · : ~i:_ i;' (; :~-'.') ::~1 (':~ 'ii! -- : 128i 17! 56' ~: :!-'-'i ;::) .'-'.,!, Ou ~TJ=l 29.2 (~. 72 83 C:~~'.~, ¢~ 'AP_I 2_9._6~ 80 F ; ..... '~ :i:) :;~) -~.! 0:~ 128 2 5:1C:~ ~ / ~)ii APl 29.2 @:75 F ~ ~! ~::! ~,,~ ,:;! ~ 128 ,~ ri,! APl 29_.4 @.77'F 17! 56! ....... 18i 55i 2o! 581 !..-'-;~ C~ 4:.~., &~.~ 128~ 20'. 56', ~, ;~;) ;;) ~:.~ ~:~ ~1 29.8~_ 81F : · 15: 57:; ..... i, ~i:i ~;:i 4;-I ~;) '8~ F ......... ;,¢J5~4::1 (~ ~1 29.6 ~ ~ ~ ;:~ 4:;Z ~ 20! ~7:~ ~ ~:~ ~::~ 4 ~: · ~:~ ~1 29.8 ~. 92 F ; --~ ........ ,; ~a .;-) ~; :. 5u ..... {~g~'15; 57{ ........... ;; :::~ [:~ 4~: ~ ~-~ ~1 30.0 ~ 88 F ~ ~::: [:3 4~ ~-:) ; 128' 15~ 57: [~ ~::: 4¢4 i::~ ~1 30.0~_88 F ........ ............. '~-~7 i~: {~:4 l/ SWACO ir ~?~ng.C-tan~ I~ ::;~: 4~' cc~'. 128; 15~ 58' In :::: (~i; t~;. ~::~ ~1 30.2_~:98 F 10 E; ¢g 4[" · ~ SWACO injected ~tank ............. ' In ~:; 0C 4~;', ~: [ SWACO injecBng ~taqk ... II ::::~ic 4';~ ,::: 128i ' 17':- I I ~; 4~.~: c:; ~1 30.1 ~8 F ...... ~ =.- :..; =~:; 4~:/~;.: .... ~ '1/[; 16[ 66: . . ~ ......... :.: :~t4!~/ ::~; ~1Gra~'30.3 ~ :;J ~ ' ~: ::~ :~;: 4~:~ ~:c SWACO inj[~~:, ,~ -F ...... iJ ;'J :~;= 4L:; ;~ ~1 30.0 ~ 92 F · . i~ ;~ ~: ,;;~i i I/q 11 ;, 577 ............ = .... 14 ~-: :l 4~:, :~;~ ~1 29.8 ~.84 F.: '~; :iii :)3 41' ¢U ' Iz:~ 12~ .~,: ...... 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Page 1 of 17 Operations Summar Report Legal Well Name: Redoubt Unit #2 ,Common Well Name: Redoubt Unit #2 Spud Date: 'Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 ........ ,.D__~!_e ............ __F_r_°_m._'__T_o_..._H_O_U_!_S_L_...~o_d.,e_,_.c_S(~db~_l__P_.h_a__.s_~_L ........................... .D__e..s_c r_iP_ .~!_ _o..n.__o..f_..o_p...e.!_a_t '_o_n_~_ ....................................................... 2/23/2001 100:00 - 06:00 I 6.00 14 A [DRLIN1 NIPPLE UP DIVERTER SYSTEM, CHANGE OUT SAVER SUB ON 06:00 I [ TOP DRIVE 2/24/2001 - 09:30 3.50 01 A I DRLIN1 CHANGE OUT SAVER SUB ON TOP DRIVE, SERVICE TOP DRIVE, I I INSTALL RISER MUD GUARD, CLEAN CELLAR AREA, WHILE MIXING SPUD MUD 09:30 - 10:30 1.00 01 A DRLIN1 SET UP RIG FLOOR, FOR PICKING UP BHA #1 10:30 - 11:30 1.00 14 A DRLIN1 FUNCTION TEST DIVERTER SYSTEM, PIT LEVEL SENSORS, i COMBUSTIBLE GAS ALARMS WITH A.O.G.C.C.REP AS WlTTNESS 11:30 - 14:30 3.00 27 DRLIN1 STRAP, DRIFT & PICK UP BHA #1 & 17 1/2" BIT RR#1 14:30 - 17:00 2.50 05 A ; DRLIN1 CIRC & COND MUD (FOAMY), CHECK FOR LEAKS IN SYSTEM 17:00 - 18:00 1.00 02 A DRLIN1 DRILL 17 1/2" HOLE, (25' OF OPEN HOLE) 18:00-22:30 4.50 27 DRLIN1 CHANGE OUT BHATO 18 1/2" BIT&2-18 1/2"STABS, 18"STABON MUD MOTOR, UBHO, ORIENT MUD MOTOR WITH MWD & TEST SIGNAL 22:30 - 01:00 2.50 08 E DRLIN1 INSTALL FAB SPACER BUSHINGS ON EACH SIDE ON TOP DRIVE LINKS TO ENHANCE THE LOAD PATH FROM TOP DRIVE TO TRAVEL BLOCK 01:00 - 02:00 1.00 27 DRLIN1 MAKE UP BHA #2, BIT #2, 18 1/2" ASSY. CHECK MWD SIGNAL 02:00 - 02:30 0.50 03 A DRLIN1 REAM FROM 143' TO 168' 02:30 - 06:00 3.50 02 A DRLIN1 DRLG W/BHA #2, BIT #2, GYRO SURVEY @ 30' INTERVALS 2/25/2001 06:00 - 07:00 1.00 05 A ClRC HOLE CLEAN, TROUBLE SHOOT GYRO TOOL 07:00- 16:30 9.50 02 A DRLIN1 DRILL WITH BHA #2, BIT #2,18 1/2" SURFACE HOLE 16:30 ~ 18:00 1.50 06 A DRLIN1 POH TO CLEAN UNDER SHAKERS AND CLEAN SHALE & GRAVEL FROM LEAKING BY-PASS SHAKER GATE 18:00 - 20:30 2.50 25 DRLIN1 CLEAN UNDER SHAKERS AND CLEAN SHALE & GRAVEL FROM LEAKING BY-PASS SHAKER GATE 20:30 - 21:30 1.00 03 A DRLIN1 RIH, REAM FROM 250' TO 567' 21:30 - 22:30 1.00 10 D DRLIN1 SURVEY WITH MWD & GYRO 22:30 - 00:00 1.50 02 A DRLIN1 DRILL SURFACE HOLE WITH BHA #3, BIT #2RR1 00:00 - 00:30 0.50 10 D DRLIN1 SURVEY WITH MWD & GYRO 00:30 - 06:00 5.50 02 A DRLIN1 DRILL SURFACE HOLE 2/26/2001 06:00 - 13:00 7.00 02 A DRLIN1 DRILL 18 1/2" SURFACE HOLE, WITH BHA #3, BIT #2RR1, HAVING DIFFICULTY GETTING SURVEYS, KEEPING PUMPS PRIMED & CARRYING CUTTINGS OUT OF HOLE DUE TO FOAM LAIDEN MUD 13:00- 15:00 2.00 06 A DRLIN1 POH 15:00 - 22:00 7.00 25 DRLIN1 CLEAN PITS, MIX NEW BATCH OF SPUD MUD (850 BBLS), REPAIR BLOWER HOSE ON TOP DRIVE 22:00 - 23:30 1.50 06 A DRLIN1 RIH WITH BHA #4, BIT ~ RR 3 23:30 - 00:30 1.00 05 A DRLIN1 CIRC, DISPLACE & DUMP FOAMY MUD FROM HOLE 00:30 - 06:00 5.50 02 A DRLIN1 DRILL SURFACE HOLE, MWD & GYRO SURVEY AT 100' i INTERVALS 2/27/2001 06:00 - 15:30 9.50 02 IA DRLIN 1 DRILL 18 1/2" HOLE. DISCONTINUE GYRO AT 1500'. MWD SURVEYS THEREAFTER. 1,5:30 - 16:00 0.50 07 DRLIN1 RIG SERVICE i 16:00 - 06:00 14.00 02 A DRLIN1 DRILL AHEAD MAKING THE FINAL BUILD SECTION. 2/28/2001 06:00 - 20:00 14.00 02 A DRLIN1 DRILLING 18 1/2" HOLE 20:00 - 20:30 0.50 07 DRLIN1 RIG SERVICE. 20:30 - 06:00 9.50 02 A DRLIN1 DRILLING AHEAD. 3/1/2001 06:00- 11:00 5.00 02 A DRLIN1 DRILLING 18 1/2" HOLE. 11:00 - 14:30 3.50 05 A DRLIN1 CIRCULATE FOR BHA TRIP 14:30 - 18:30 4.00 06 J DRLIN1 TRIP OUT AND CHANGE BHA FOR CLEAN OUT RUN. SLM. NO CORRECTION. 18:30 - 22:00 3.50 25 DRLIN1 ASSEMBLE SURFACE CASING LANDING JOINTS. Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 2 of,17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date [i FrOm - To I Hours Code ICode~SUb Phase Description of Operations' 3/1/2001 18:30 - 22:00 3.50 25 ] DRLIN1 PASS CASING HANGER THROUGH STACK CHECKING . CLEARANCE. SET ASIDE LANDING JOINTS. 22:00 01:00 3.00 06 J DRLIN1 FINISH MAKING UP STIFF ASSEMBLY. LAY DOWN MWD. ' RUN IN THE HOLE. NO PROBLEMS. 01:00-05:30 4.50 02 A :DRLIN1 DRILLTO 18 I/2"TD. 05:30 - 06:00 0.50 05 F . DRLIN1 CIRCULATE TO RUN CASING. 3/2/2001 06:00 - 08:00 2.00 05 A DRLIN1 CIRCULATE AT TD 3226' FOR CASING. 08:00 - 12:00 4.00 06 A DRLIN1 POH. SET ASIDE BHA. BREAK BIG STABALIZER BLADES. 12:00 - 03:30 15.50 12 A CSGSUR RIG UP AND RUN 13 3~8" SURFACE CASING WITH SPIRAL GLIDER AND BOW SPRING CENTRALIZERS, SHOE, FLOAT COLLAR, LANDING COLLAR AND HALLIBURTON ES CEMENTER. BAKER LOCK AS NECESSARY. BREAK CIRCULATION AT 2100'. NO HOLE PROBLEMS. 03:30 - 04:30 1.00 05 F CSGSUR CIRCULATE HOLE CLEAN AT 3150'. 04:30 - 06:00 1.50 12 A CSGSUR PICK UP LANDING JOINTS, VETO GRAY CSG HANGER AND CEMENT HEAD. LAND CASING AND RIG TO CEMENT. 3/3/2001 06:00 - 07:00 1.00 12 A CSGSUR PICK UP LANDING JOINTS AND TAG LANDER. 07:00 - 08:30 1.50 12 A CSGSUR CIRCULATE AND RECIPROCATE CASING. 240 UP. 170 DN. 10 B/M @ 1050 PSI. 08:30 - 12:00 3.50 12 A CSGSUR CEMENT FIRST STAGE. BUMPED PLUG. LANDED CASING WITH 120,000 # ON HANGER. 12:00 - 13:00 1.00 12 A CSGSUR LOAD SECOND STAGE CLOSING PLUG. OPEN ES CEMENTER AT 2017' WITH 2350 PSI. 13:00 - 19:30 6.50 12 A CSGSUR CIRC THROUGH ES CEMENTER, WAIT ON CEMENT AND DRILL WATER FROM WORK BOAT. 19:30 - 20:00 0.50 12 A CSGSUR SAFETY MEETING AND PRIME UP BJ SERVICES. 20:00 - 23:30 3.50 12 A CSGSUR PUMPED 2ND STAGE CEMENT THROUGH ES CEMENTER. CLOSE COLLAR WITH 1750 PSI. HOLD 1750 PSI FOR 5 MIN, BLEED OFF AND CHECK FOR FLOW. 23:30 - 02:00 2.50 12 A CSGSUR RIG DOWN LANDING JOINTS AND CASING TOOLS. 02:00 - 06:00 4.00 14 A CSGSUR NIPPLE DOWN DIVERTER. 3/4/2001 06:00 - 07:00 1.00 14 A CSGSUR FINISH NIPPLE DOWN DIVERTER. 07:00 - 07:30 0.50 14 B DRLIN1 N/U MULTIBOWL WELL HEAD. TEST SEALS TO 1000 PSI. 07:30 - 05:00 21.50 14 B DRLIN1 N/U BOP. CHANGE RAM POSITIONS. ADJUST FLOW NIPPLE. 05:00 - 06:00 1.00 15 A DRLIN1 TEST BOP. 3/5/2001 06:00 - 08:30 2.50 15 A DRLIN1 FINISH TESTING BOP AND SET WEAR BUSHING. 08:30 - 09:30 1.00 07 DRLIN1 RIG SERVICE. 09:30 - 14:00 4.50 06 A DRLIN1 ~MAKE UP 12 1/4" BHA WITH BIT # 3. 14:00 - 15:30 1.50 06 A : DRLIN1 RIH. CLEAN OUT 17' OF CEMENT TO 2017'. 15:30 - 16:30 1.00 05 A ' DRLIN1 CIRCULATE OUT CONTAMINATED MUD. 16:30 - 17:00 0.50 25 DRLIN1 TEST CASING TO 3000 PSI. GOOD TEST. 17:00 - 22:00 5.00 25 i DRLIN1 DRILL OUT ES CEMENTER AT 2017'. 22:00 - 22:30 0.50 25 DRLIN1 TEST CASING TO 3000 PSI. GOOD TEST. 22:30 - 01:00 2.50 06 A DRLIN1 RIH. TAGGED CEMENT AT 3106'. CLEAN OUT TO 3126'. 01:00 - 02:00 1.00 05 A DRLIN1 CIRCULATE OUT CONTAMINATED MUD. 02:00 - 03:00 1.00 25 DRLIN1 TEST CASING TO 3000 PSI FOR 30 MINUTES. GOOD TEST. 03:00 - 06:00 3.00 25 DRLIN1 CLEANING OUT FROM LANDING COLLAR AT 3126'. 3/6/2001 06:00 - 07:00 1.00 25 I DRILL 13 3/8" CASING FLOAT EQUIP, DRILL OPEN HOLE FROM SHOE @ 3212' TO 3246' 07:00 - 08:00 1.00 05 A DRLIN2 CIRC & COND FOR LEAK OFF TEST 08:00 - 09:00 1.00 25 DRLIN2 PERFORM LEAK OFF TEST, BROKE DOWN @ 800 PSI = 14.1 PPG EMW 09:00-00:00 15.00 02 A DRLIN2 DRILL 12 1/4" HOLE WITH BHA#6, BIT#3 Printed: 712312001 9:42:56AM FOREST OIL CORP. Page 3 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 =Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date· From-To~/Hours 11 Code,_l / ~°uclbe '! Phase [I Description of Operationsl / 3/6/2001 [00:00 - 00:30 0.50 05 A DRLIN2 GIRO SWEEP TO SURFACE 00:30 02:00 1.50 06H ' DRLIN2 POH TO 13 3/8" CASING SHOE, TIGHT @ 3393' & 3700' (40 TO 48 K ' 0.50 DRLIN2 OVER PULL) 02:00 - 02:30 07 SERVICE RIG & TOP DRIVE 02:30 03:30 i 1.00 06 H DRLIN2 RIH, WASH FROM 3938' TO 4031' 03:30 06:00 2.50 02 A DRLIN2 DRILLAHEAD 3/7/2001 06:00 - 12:00 6.00 02 A DRLIN2 DRILL 12 1/4" HOLE WITH BHA # 6, BIT # 3 12:00 - 12:30 0.50 10 E DRLIN2 SERVICE RIG, CIRC UP SURVEY 12:30 - 14:30 2.00 02 A DRLIN2 DRILL AHEAD 14:30 - 16:00 1.50 05 A DRLIN2 CIRC SWEEP AROUND, CHECK FLOW, PUMP PILL 16:00 - 17:00 1.00 06 H DRLIN2 SHORT TRIP TO 4031' & BACK TO BOTTOM (GOOD TRIP, NO FILL ON BOTTOM) 17:00 - 06:00 13.00 02 A DRLIN2 DRILL AHEAD 3/8/2001 06:00 - 12:00 6.00 02 A DRLIN2 DRILL 12 1/4" HOLE WITH BHA #6, BIT#3 12:00 - 13:30 1.50 05 A DRLIN2 CIRC SWEEP AROUND, CHECK FLOW, PUMP DRY JOB 13:30 - 15:00 1.50 06 H DRLIN2 SHORT TRIP TO 13 3/8" CASING SHOE, (GOOD TRIP) 15:00 - 17:30 2.50 07 DRLIN2 SERVICE RIG, TOP DRIVE, BLOCKS, ADJUST TOP DRIVE TORQUE RAIL & GUIDES 17:30 - 19:00 1.50 09 DRLIN2 CUT & SLIP 75' DRILLING LINE 19:00 - 22:00 3.00 06 A DRLIN2 STRAP, DRIFT & P/U 75 JOINTS OF 5" S135 DRILL PIPE 22:00 - 22:30 0.50 06 A DRLIN2 RIH WITH 5 STANDS FROM DERRICK, BREAK GIRO, WASH BOTTOM 90' OF HOLE, NO FILL 22:30 - 06:00 7.50 02 A DRLIN2 DRILL AHEAD 3/9/2001 06:00 - 00:00 18.00 02 A DRLIN2 DRILL 12 1/4" HOLE WITH BHA#6, BIT #3, FROM 6455' TO 7160' 00:00 - 01:00 1.00 05 A DRLIN2 CIRC SWEEP AROUND WITH COAL GAS, CHECK FLOW, PUMP DRY JOB 01:00 - 03:00 2.00 06 H DRLIN2 SHORT TRIP TO 13 3/8" CASING SHOE, TIGHT SPOTS @6711', 6540' & 6311' WITH 25 TO 30K + OVER PULL 03:00 - 04:00 1.00 07 DRLIN2 CUT & SLIP 60' OF DRILL LINE, SERVICE RIG 04:00 - 06:00 2.00 06 H DRLIN2 RIH (GOOD TRIP), TAG BOTTOM WITH 6' OF FILL, BREAK CIRC 3/10/2001 06:00 - 00:00 18.00 02 A DRLIN2 DRILL 12 1/4" HOLE WITH BHA #6, BIT #3 FROM 7160' TO 7580' 00:00 - 01:00 1.00 05 A DRLIN2 GIRO SWEEP AROUND, CHECK FLOW 01:00 - 02:30 1.50 06 H DRLIN2 POH TO 6000' (GOOD TRIP) 02:30 - 03:00 0.50 07 DRLIN2 SERVICE RIG & TOP DRIVE 03:00 - 03:30 0.50 06 H DRLIN2 RIH, BREAK GIRO, NO FILL '03:30 - 06:00 2.50 02 A DRLIN2 DRILL AHEAD FROM 7580' TO 7638' :3/11/2001 06:00 - 15:30 9.50 02 A DRLIN2 DRILL WITH BHA #6, BIT#3 FROM 7638' TO 7832' 15:30 - 16:30 1.00 05 A DRLIN2 ClRC UP SWEEP, CHECK FLOW, MIX DRY JOB 16:30 - 20:00 3.50 06 A DRLIN2 POH, GOOD TRIP 20:00 - 22:00 2.00 27 DRLIN2 SERVICE MWD, CLEAN STABS & BIT OF CLAY BUILD UP, CHANGE OUT BIT, STAND BACK IN DERRICK 22:00 - 01:00 3.00 15 A DRLIN2 PULL WEAR RING, TEST BOPE EQUIP FROM 250 PSI TO 5000 PSI, HYDRIL BAG FROM 250 PSI TO 3500 PSI, PERFORM TIME / PRESSURE TEST ON KOOMEY UNIT, TEST COMBUSTIBLE GAS ALARMS, INSTALL WEAR RING 01:00 - 03:00 2.00 27 DRLIN2 CLEAN RIG FLOOR, M/U & RIH WITH BHA#7, CHECK MWD SIGNAL (OK) 03:00 - 04:00 1.00 06 A DRLIN2 RIH TO 13 3/8" SHOE, FILL PIPE 04:00 - 04:30 0.50 07 DRLIN2 SERVICE RIG & TOP DRIVE 04:30 - 06:00 1.50 06 A DRLIN2 RIH WITH BHA #7, BIT # 4 3/12/2001 06:00 - 06:30 0.50 06 A DRLIN2 RIH WITH BHA #7, BIT #4 06:30 - 07:00 0.50 03 A DRLIN2 BREAK CIRC, WASH & REAM FROM 7736' TO 7832' 07:00 - 03:30 20.50 02 A DRLIN2 DRILL 12 1/4" HOLE FROM 7832' TO 8165' Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 4 of 17 Operations Summary Report , Legal Well Name: Redoubt Unit #2 'Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date From-TojHours Code cSoUdbe/Phase/ Description of Operations 3/12/2001 03:30 - 04:00 0.50 08 E DRLIN2 iTROUBLE SHOOT & REPAIR SCR PROBLEM 04:00 - 06:00 [ 2.00 02 A DRLIN2 DRILL AHEAD FROM 8165' TO 8195' 3/13/2001 06:00 - 07:30 1.50 02 A DRLIN2 DRILLING FROM 8195' TO 8211' 07:30 - 09:00 1.50 05 A DRLIN2 CIRCULATE BOTTOMS UP FOR SHORT TRIP. 09:00 - 12:30 3.50 08 E DRLIN2 SHORT TRIP. RIG DEVELOPED SCR PROBLEMS. POH TO SHOE. 12:30 - 17:00 4.50 08 E DRLIN2 REPAIR SCR. 17:00 - 18:30 1.50 06 H i DRLIN2 RIH. NO FILL ON BOTTOM. 18:30 - 06:00 11.50 02 A , DRLIN2 DRILLING AHEAD. 3/14/2001 06:00 - 15:00 9.00 02 A DRLIN2 DRILLING WITH BIT # 4. 15:00- 16:00 1.00 05 A DRLIN2 CIRCULATE, SURVEY AND DRY JOB. 16:00 - 22:00 6.00 06 A DRLIN2 ;TRIP FOR BIT. CHANGE MUD MOTOR AND JARS (HRS) 22:00 - 01:30 3.50 06 A DRLIN2 RIH TO SHOE. FILL PIPE. 01:30 - 02:00 0.50 07 DRLIN2 RIG SERVICE. 02:00 - 04:00 2.00 06 A DRLIN2 RIH. NO HOLE PROBLEMS. 04:00 - 05:00 1.00 03 A DRLIN2 REAM 90' TO BOTTOM. 05:00 - 06:00 1.00 02 A DRLIN2 DRILL WITH BIT # 5. 3/15/2001 06:00 - 06:00 24.00 02 A DRLIN2 DRILL AHEAD WITH BIT # 5. 3/16/2001 06:00 - 10:30 4.50' 02 A DRLIN2 DRILL TO CASING DEPTH WITH BIT # 5. 10:30 - 12:30 2.00, 05 I DRLIN2 CIRCULATE AND CONDITION MUD. 12:30 - 14:00 1.50 06 H DRLIN2 SHORT TRIP. CLEANED BRIDGE AT 8560'. 14:00- 16:30 2.50 05 . A DRLIN2 CIRCULATE AND CONDITION HOLE. 16:30 - 22:00 5.50 06 J DRLIN2 POH WITH BIT # 5. LAY DOWN MWD. 22:00 - 05:00 7.00 11 A DRLIN2 LOG WITH SCHLUMBERGER QUAD COMBO TO 8984' 05:00 - 06:00 1.00 27 DRLIN2 MAKE UP CLEAN OUT ASSEMBLY. 3/17/2001 06:00 - 08:00 2.00 06 H DRLIN2 BHA. RIH TO SHOE WITH CLEAN OUT ASSEMBLY. 08:00 - 09:00 1.00 09 DRLIN2 SLIP AND CUT DRILLING LINE. 09:00 - 09:30 0.50 07 DRLIN2 SERVICE TOP DRIVE. 09:30 - 11:30 2.00 06 H DRLIN2 RIH. TAG BRIDGE AT 8971'. 11:30 - 12:00 0.50 06 H DRLIN2 CLEAN OUT BRIDGE. WASH TO BOTTOM. 12:00 - 16:30 4.50 05 F DRLIN2 CIRCULATE AND CONDITION MUD. 16:30 - 20:00 3.50 06 H DRLIN2 SHORT TRIP TO 8100'. 20:00 - 03:00 7.00 06 H DRLIN2 POH. LAY DOWN BHA. 03:00 - 05:30 2.50 25 G DRLIN2 INJURY ON RIG FLOOR. MEDIVAC. 05:30 - 06:00 0.50 06 G DRLIN2 FINISH LAY DOWN BHA. 3/18/2001 06:00 - 10:00 4.00 25 CSGIN1 PULL WEAR BUSHING. CHANGE AND TEST PIPE RAMS. 10:00 - 14:00 4.00 12 A CSGIN1 RIG TO RUN CASING. CHANGE BALES. R/U TOOLS. 14:00 - 06:00 16.00 12 A CSGIN1 RUN 9 5/8" CASING. BREAK CIRCULATION AT SHOE AND 5700'. 3/19/2001 '06:00 - 11:30 5.50 12 A CSGIN1 RUN 9 5/8" CASING TO TD WITHOUT ANY HOLE PROBLEMS. BREAK CIRCUALTION PERIODICALLY. 11:30 - 13:00 1.50 12 A CSGIN1 TAG CASING HANGER. UNABLE TO RECIPROCATE. SET 200,000# ON HANGER. RIG TO CEMENT. 13:00 - 18:00 5.00 12 A CSGIN1 CIRCULATE 18:00 - 22:00 4.00 12 A CSGIN1 MIX AND PUMP CEMENT. DISPLACE WITH OIL BASE MUD. 22:00 - 06:00 8.00 25 CSGIN1 CLEAN MUD PITS. PREPARE FOR OIL BASE MUD. 3/20/2001 06:00 - 12:00 6.00 25 CSGIN2 CLEAN PITS, WHILE HANG DOOR ON DERRICK HOUSE, CHANGE OUT AIR HOSE ON TOP DRIVE BLOWER, 12:00 - 19:30 7.50 25 CSGIN2 CLEANING PITS IN PREP TO TAKE ON OBM, CHANGE OUT PIPE i RAMS FROM 9 5/8" TO 5", LAY DOWN CEMENT HEAD & LANDING ; ~ JOINTS 19:30 - 22:00 2.50 25 CSGIN2 RUN IN & SET13 3/8" X 9 5/8" PACK OFF SLEAVE, RUN IN LOCK DOWNS & TEST TO 5000 PSI FOR 30 MINS 22:00 - 00:00 2.00 25 CSGIN2 FINISH CLEANING PITS, WELD WALK AROUND BRACES AT DERRICK BOARD Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 5,:of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 'Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date 1 From -To Hours Code Sub Phase Description of Operations 3/20/2001 00:00 - 01:00 1.00115 A CSGIN2 RIG DOWN PACK OFF RUNNING TOOL, MAKE UP & SET TEST I I PLUG 01:00 - 03:00 ' 2.00 15 A I CSGIN2 TAKE ON O.B.M. INTO PITS, RIG UP TO TEST BOPS 03:00 - 06:00 3.00 15 A I CSGIN2 TEST BOPE, FROM 250 PSI TO 5000 PSI, TEST HYDRIL BAG FROM 250 PSI TO 3500 PSI 3/21/2001 06:00 - 08:00 2.00 15 A DRLIN3 TEST BOPES, INSTALL WEAR BUSHING 08:00 - 09:00 1.00 25 DRLIN3 CHANGE OUT TOP DRIVE BALES 09:00 - 11:30 2.50 27 DRLIN3 LAYING DOWN 12 1/4" BHA # 9 11:30 - 12:00 0.50 DRLIN3 BEGIN TO STRAP, DRIFT & PICK UP 8 1/2" BHA #10 12:00 - 16:00 4.00 26 DRLIN3 PICK UP 69 JOINTS OF 5" S135 16:00 - 16:30 0.50 07 DRLIN3 SERVICE RIG 16:30 - 17:30 1.00 26 DRLIN3 STAND BACK STANDS OF 5" DRILL PIPE IN DERRICK 17:30 - 00:00 6.50 27 DRLIN3 CONTINUE PICKING UP BHA #10, BIT #6, ORIENT MUD MOTOR WITH MWD, CHECK MWD SIGNAL (GOOD) 00:00 - 03:00 3.00 06 A DRLIN3 RIH, TAG CEMENT WITH 10K BIT WEIGHT @ 8848' 03:00 - 03:30 0.50 05 A DRLIN3 BREAK ClRC & PREP TO TEST 9 5~8" CASING 03:30 - 04:00 0.50 12 D DRLIN3 TEST 9 5~8" CASING TO 3000 PSI FOR 30 MINS. (GOOD TEST) '04:00 - 06:00 2.00 12 D DRLIN3 BREAK ClRC, BEGIN DRILLING CEMENT FROM 8848' TO 8920' HARD DRILLING FROM 8848' TO 8858' SOFT FROM 8858' TO 8870' I HARD TO 8820' 3/22/2001 06:00 - 06:30 0.50 12 D DRLIN3 TEST 9 5~8" CASING TO 3000 PSI FOR 30 MINS @ LANDING COLLAR (GOOD TEST) 06:30 - 08:30 2.00 02 D DRLIN3 DRILL LANDING COLLAR, 80' OF CEMENT & 9 5/8" CASING SHOE 08:30 - 10:00 1.50 25 DRLIN3 DRILL FROM 9029' TO 9049', PERFORM FORMATION INTEGRITY TEST: 10.5 PPG EMW WITH 8.9 PPG MUD 67565' TVD - 630 PSI SURFACE PRESSURE (GOOD TEST) 10:00 - 06:00 20.00 02 A DRLIN3 DRILL 8 1/2" HOLE WITH BHA #10, BIT #6 FROM 9049' TO 9865' 3/23/2001 06:00 - 11:30 5.50 02 A DRLIN3 DRILL 8 1/2" WITH BHA #10, BIT #6 FROM 9865' TO 10006' 11:30 - 12:00 0.50 05 A ; DRLIN3 CIRC AROUND SWEEP, CHECK FLOW, MIX & PUMP DRY ,JOB 12:00 - 13:00 1.00 06 H DRLIN3 SHORT TRIP TO 9 5~8" SHOE, (TIGHT SPOTS @ 9515' & 9450') 13:00 - 13:30 0.50 07 DRLIN3 SERVICE RIG & TOP DRIVE, CHANGE OUT SAVER SUB 13:30 - 15:00 1.50 06 H DRLIN3 RIH, WASH FROM 9050', 9080' TO 9140' (BRIDGES) 15:00 - 15:30 0.50 03 A DRLIN3 REAM FROM 9976' TO 10006' 15:30 - 06:00 14.50 02 A DRLIN3 DRILL FROM 10006' TO 10450' 3/24/2001 06:00 - 10:00 4.00 02 A DRLIN3 DRILL 8 1/2" HOLE WITH BHA #10, BIT #6 FROM 10450' TO 10548' 10:00 - 11:00 1.00 05 A DRLIN3 CIRC SWEEP AROUND, CHECK FLOW, PUMP DRY JOB 11:00 - 14:00 3.00 06 H DRLIN3 SHORT TRIP TO 9 5/8" SHOE, TIGHT SPOTS @ 9740' TO 9357' 14:00 - 16:00 2.00 07 DRLIN3 SERVICE RIG, CHANGE OIL IN TOP DRIVE, SERVICE TOP DRIVE 16:00 - 16:30 0.50 06 H DRLIN3 RIH, REAM FROM 10488' TO 10548' 16:30 - 06:00 13.50 02 A DRLIN3 DRILL FROM 10548' TO 10900' 3/25/2001 06:00 - 10:30 4.50 02 A DRLIN3 DRILL 8 1/2" HOLE WITH BHA #10, BIT #6 FROM 10900' TO 11001' 10:30 - 11:00 0.50 05 A DRLIN3 CIRC SWEEP AROUND, CHECK FLOW, PUMP DRY JOB 11:00 - 14:30 3.50 06 H DRLIN3 SHORT TRIP TO 9 5~8" SHOE, WORK THROUGH TIGHT SPOTS @ 10610', 9750' TO 9630' 14:30 - 15:00 0.50 07 DRLIN3 SERVICE RIG 15:00 - 16:00 1.00 06 H DRLIN3 RIH (GOOD TRIP) 16:00 - 16:30 0.50 03 A DRLIN3 REAM FROM 10971' TO 11001' 16:30 - 06:00 13.50 02 A DRLIN3 DRILL 8 1/2" HOLE WITH BHA #10, BIT #6 3/26/2001 06:00-07:00 1.00 02 A DRLIN3 DRILL 8 1/2" HOLE WITH BHA #10, BIT#6, FROM 11220'TO 11250' 07:00 - 08:00 1.00 05 A DRLIN3 CIRC BOTTOMS UP, CHECK FLOW, PUMP DRY JOB 08:00 - 09:00 1.00 06 A DRLIN3 POH TO 9 5~8" CASING SHOE, (GOOD TRIP) 09:00 - 10:00 1.00.07 C DRLIN3 REPAIR AIR LEAK ON LOW DRUM CLUTCH QUICK RELEASE, ! SERVICE TOP DRIVE & DRAWWORKS Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 6 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date From-To Hours Code lcSoUdbe' Phase/ DescriptionofOperations . 3/26/2o01 i 10:00 - 11:00 1.00[ 25 i DRLIN3 ABANDON PLATFORM DRILL 3.50~ 06 A ' DRLIN3 POH TO BHA 14:30 - 15:30 1.00 27 DRLIN3 CHANGE OUT MWD TOOL, BIT & FLOAT 15:30 - 19:00 3.50 06 A DRLIN3 RIH TEST MWD, FILL PIPE @ 4500' & 9000' 9 5/8" CASING SHOE 19:00 - 20:00 1.00 09 I DRLIN3 SLIP & CUT 75' OF DRILLING LINE 20:00 - 21:30 1.50 06 A DRLIN3 RIH, (GOOD TRIP) 21:30-22:00 0.50 03 A DRLIN3 REAM FROM 11160' TO 11250' 22:00-06:00 8.00 02 A DRLIN3 DRILL WITH BHA#11, BIT#7 FROM 11250'TO 11441' 3/27/2001 06:00 - 04:30 22.50 02 A DRLIN3 DRILL AHEAD WITH BIT # 7. 04:30 - 05:00 0.50 05 A DRLIN3 CIRCULATE & SURVEY 05:00 - 06:00 1.00 06 H DRLIN3 SHORT TRIP TO 11050'. PICKING UP SINGLES OF DRILL PIPE ON THE WAY BACK IN THE HOLE. 3/28/2001 06:00 - 00:00 18.00 02 A DRLIN3 I DRILL AHEAD. 00:00- 01:00 1.00 05 A DRLIN3 I CIRCULATE. 01:00 - 06:00 5.00 06 A DRLIN3 POH WITH BIT # 7. 3/29/2001 06:00 - 10:00 4.00 15 A DRLIN3 TEST BOP 10:00- 11:00 1.00 06 A DRLIN3 BHA 11:00 - 13:00 2.00 06 A DRLIN3 PICK UP 5" DRILL PIPE 13:00 - 13:30 0.50 07 'DRLIN3 RIG SERVICE 13:30 - 17:00 3.50 06 A DRLIN3 RIH. FILL PIPE. 17:00 - 17:30 0.50 03 A DRLIN3 REAM 30' TO BOTTOM. 17:30 - 19:30 2.00 05 A DRLIN3 CIRCULATE OUT THICK MUD AND CUTTINGS. 19:30 - 06:00 10.50 02 A DRLIN3 DRILLING AHEAD WITH BIT # 8. 3/30/2001 06:00 - 04:00 22.00 02 A DRLIN3 DRILLING FROM 12388' TO 12815'. 04:00 - 05:00 1.00 05 A DRLIN3 CIRCULATE AND DRY JOB. 05:00 - 06:00 1.00 06 A DRLIN3 TRIP FOR BIT # 8. WORK TIGHT HOLE AT 12135'. 3/31/2001 06:00 - 13:00 7.00 06 A DRLIN3 POH WITH BIT # 8. WORK TIGHT COAL AREAS 12135' TO 11900'. TIGHT AGAIN AT 11525'. 13:00 - 14:00 1.00 07 DRLIN3 RIG SERVICE. REPACK DRAW WORKS SPEAR. 14:00 - 21:30 7.50 06 A DRLIN3 BHA. PICK UP BIT # 9. CHANGE MUD MOTORS.CHECK MWD. SURFACE TEST MWD. FILL PIPE AND BREAK CIRCULATION AT SHOE. 21:30 - 23:30 2.00 09 DRLIN3 CUT AND SLIP DRILLING LINE. 23:30 - 02:00 2.50 06 A DRLIN3 RIH. WORK THROUGH TIGHT COALS. 02:00 - 05:00 3.00 03 A DRLIN3 TIGHT AT 12450. REAM AND CLEAN TO BOTTOM. 05:00 - 06:00 1.00 02 A DRLIN3 DRILLING FROM 12815' TO 12841'. 4/1/2001 06:00 - 06:00 24.00 02 A DRLIN3 DRILLING AHEAD WITH BIT # 9. 4/2/2001 06:00 - 11:00 5.00 02 A DRLIN3 DRILL WITH BIT # 9 FROM 13163' TO 13255'. 11:00 - 13:00 2.00 05 A DRLIN3 CIRCULATE THE HOLE CLEAN. 13:00 - 16:30 3.50 06 A DRLIN3 POH TO SHOE. TIGHT IN AREAS OF COAL. 12990'-12627'. 12124'-12000' AND 10850'-10840'. NO UPREAMING NEEDED. 16:30 - 20:30 4.00 06 A DRLIN3 FINISH POH. 20:30 - 02:30 6.00 06 A DRLIN3 PICK UP BIT # 10. PULSE TEST MWD. RIH TO SHOE. 02:30 - 03:30 1.00 06 A DRLIN3 RIG SERVICE. BREAK CIRCULATION. 03:30 - 06:00 2.50 06 A DRLIN3 RIH WITH BIT # 10. CLEAN OUT TIGHT SPOT AT 12775'. WASHING 90' TO BOTTOM AT REPORT TIME. 4/3/2001 06:00 - 07:00 1.00 03 A DRLIN3 RIH, CIRC & WASH / REAM FROM 12750' TO 13137' 07:00 - 08:00 1.00 05 A DRLIN3 CIRC THICK MUD & BOTTOMS UP TRIP GAS OF 208 UNITS 08:00- 06:00 22.00 02A DRLIN3 DRILL 8 1/2" WITH BHA #14, BIT #10, FROM 13255' TO 13575' 4/4/2001 06:00 - 10:30 4.50 02 IA DRLIN3 DRILL 8 1/2" HOLE WITH BHA #14, BIT#10 FROM 13575' TO 13684' 10:30 - 12:00 1.50 05 A DRLIN3 CIRC SWEEP AROUND, CHECK FLOW, PUMP SMALL DRY JOB Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. page 7 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date ' From. To Hours Code cSoUdbe' Phase Description of Operations 4/4/2001 12:00 - 14:00 ' 2.00~ 06 H ! DRLIN3 !SHORT TRIP 10 STANDS, TIGHT FROM 13550' TO 12850' WITH 50 , ITO 80 K OVER PULL (PUMP THRU) POH TO 12745', GOOD HOLE FROM 12838' TO 12745' 14:00 - 15:00 1.00 06 H DRLIN3 RIH, WORK THRU BRIDGES & LEDGES @ 12880', 13130'& 13340 15:00 - 16:30 1.50 03 A DRLIN3 BREAK ClRC @ 13620' TAG FILL - 55', WASH & REAM TO 13684' 16:30 - 01:30 9.00 02 A DRLIN3 DRILL AHEAD FROM 13684' TO 13823' 01:30 - 03:00 1.50 05 A DRLIN3 CIRC SWEEP AROUND, CHECK FLOW 03:00 - 04:30 1.50 06 A DRLIN3 POH, PUMP THRU TIGHT SPOTS 04:30 - 06:00 1.50 06 A DRLIN3 POH, GOOD HOLE FROM 12838' 4/5/2001 06:00 - 08:30 2.50 06 !A DRLIN3 POH WITH BHA #14, BIT #10 08:30 - 10:00 1.50 27 DRLIN3 CHANGE OUT JARS, MWD TOOL, BIT & FLOAT 10:00 - 17:00 7.00 15 A DRLIN3 PULL WEAR RING, TEST BOPE FROM 250 PSI TO 5000 PSI, HYDRIL BAG FROM 250 PSI TO 3500 PSI WITH A.O.G.C.C. REP AS WITTNESS, FUNCTION TEST FLOW, TRIP TANK & PVT ALARMS, KOOMEY TIME / PRESSURE TEST & COMBUSTIBLE GAS ALARMS, RESET WEAR RING 17:00 - 21:00 4.00 06 A DRLIN3 RIH, TEST MWD (GOOD TEST), BREAK ClRC @ 5000' & 9 518" CASING SHOE 9011' 21:00 - 21:30 0.50 05 A DRLIN3 ;CIRC & SHEAR O.B.M. SERVICE RIG & TOP DRIVE 21:30 - 00:00 2.50 06 A DRLIN3 RIH, HOLE IN GOOD SHAPE TO 12100', FILL DRILL PIPE, RIH, HOLE TOOK 100K DRILL STRING WEIGHT @ 12650', 12930', 13320' & MADE UP TOP DRIVE @ 13652' TO WASH THRU BRIDGE 00:00 - 02:00 2.00 03 A DRLIN3 WASH & REAM FROM 13652' TO BOTTOM @ 13823', FILL = 38', BOTTOMS UP GAS -- 439 UNITS 02:00-06:00 4.00 02 A DRLIN3 DRILLWlTH BHA#15, BIT#11 FROM 13823' TO 13875' 4/6/2001 06:00-22:00 i 16.00 02 A DRLIN3 DRILLWlTH BHA#15, BIT#11 FROM 13875' TO 14196' 22:00 - 23:00 ' 1.00 06 H DRLIN3 SHORT TRIP TO 13700', TIGHT SPOT @ 13790' - 13780' 23:00 - 00:00 1.00 06 H DRLIN3 PICK UP 3 JOINTS OF 5' DRILL PIPE, RIH, WASH FROM 14106' TO 14196', OBSERVED 3' OF FILL 00:00 - 06:00 ' 6.00 02 A DRLIN3 DRILL AHEAD FROM 14196' TO 14320' -- 67' BELOW BOTTOM TWIN COAL MARKER 4/7/2001 06:00 - 08:00 2.00 05 A DRLIN3 CIRC HIGH DENSITY/HI VIS SWEEP AROUND @ 8 1/2" T.D. OF 14320' 08:00 - 10:00 2.00 06 H DRLIN3 PUMP 10 STANDS OUT THRU TIGHT HOLE, PULL 10 STANDS WITH OUT PUMPING 10:00 - 13:00 3.00 06 H DRLIN3 RIH TO 13639', TIGHT @ 13330' - 13110' START PUMPING THRU BRIDGES @ 13816' TO 13910', WASH TO BOTTOM, OBSERVED 6' OF FILL 13:00 - 16:00 3.00 05 A DRLIN3 CIRC, PUMP HI VIS SWEEP & WEIGHT UP TO 9.6 PPG 16:00 - 19:30 3.50 06 H DRLIN3 POH, 14200' - 14160' = 60 TO 70K OVER PULL (NO PUMP), PUMP OUT FROM 14160' TO 13800' WITH 40K OVER PULL, 13800' TO 9011' (CASING SHOE) GOOD HOLE 19:30 - 20:30 1.00 09 DRLIN3 CUT & SLIP 102' OF DRILL LINE 20:30 - 01:00 4.50 06 H DRLIN3 RIH, BREAK CIRC @ 11650', RIH SLICK TO 14265' TOOK 100K STRING WEIGHT, WASH TO 14305', PUMP OUT TO 14197', TRY TO PULL OUT TO 14100' WITH OUT PUMP, PULLED 70 - 100K OVER PULL 14100' TO 14050', RIH, WASH & REAM FROM 14050' TO 14320' T.D.' 01:00 - 04:00 3.00 05 A DRLIN3 PUMP HI VIS SWEEP AROUND, CHECK FLOW 104:00 - 06:00 2.00 06 A DRLIN3 POH, PUMP OUT FROM 14224' TO 14032', POH WITH OUT PUMPING FROM 14032' TO 9011' (9 5/8" CASING SHOE) DEFINITE IMPROVEMENT IN HOLE CONDITION 4/8/2001 06:00 - 12:00 6.00 06 A DRLIN3 POH WITH BHA#15, BIT#11 (SLM) NO CORRECTION ON DRILL Printed: 712312001 9:42:56AM FOREST OIL CORP. Page 8 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: ,Rig Name: NABORS DRILLING Rig Number: 429 Date ' From-To Hours Code Sub Phase Description of Operations i Code 4/8/2001 06:00 - 12:00 6.00 06 IA DRLIN3 PIPE STRAP '12:00 - 13:00 I 1.001 27 ' EVAL 3 LAY DOWN MWD PROBE & BIT, STAND BACK BHA 13:00 - 03:30 14.50 11 A EVAL 3 PJSM, RIG UP SCHLUMBERGER EQUIP & RUN QUAD COMBO, TOOLS WOULD NOT PASS 9120', POH, CHANGE CENTRALIZER, i ADD KNUCKLE JOINT, RIH, (NO GO @ 9120'), POH, SHORTEN I TOOL CONFIGURATION, RIH (NO GO @ 9120'), POH, RIH WITH RESISTIVITY TOOL (NO GO @ 9120') POH, RIG DOWN SCHLUMBERGER EQUIP TO SIDE 03:30 - 05:30 2.00 27 EVAL 3 M/U CLEAN OUT "STIFF" ASSY. BHA #16,BIT #RR11 05:30 - 06:00 0.50 06 IA EVAL 3 RIH 4/9/2001 06:00 - 08:30 2.50 06 H EVAL 3 RIH WITH BHA #16, BIT #RR11, (STIFF CLEAN OUT ROTARY ASSY.) 08:30 - 12:00 3.50 03 C EVAL 3 REAM THRU TIGHT SPOT @ 9100' TO 9300', TAKING 25K TO 30K OF STRING WEIGHT 12:00- 15:30 3.50 06 H EVAL 3 CONTINUE RIH, WORK TIGHT SPOTS @ 12000', 12510' & 14100' TO 14180', WASH & REAM FROM 14260' TO 14320' OBSERVED 3' OF FILL 15:30 - 20:30 5.00 05 D EVAL 3 CIRC & COND MUD, PUMP SWEEP AROUND, CHECK FLOW, MIX UP DRY JOB 20:30 - 04:30 8.00 06 H EVAL 3 POH, PUMP OUT THRU 14180' TO 14100', GOOD HOLE TO 13550', PUMP DRY JOB, POH INTO 9 5/8" CASING SHOE, RIH PASS THRU WIRELINE LOG BAD SPOT @ 9120' WITH SLIGHT BOBBLE OF 5K, POH NO OVERPULL @ 9120', DROP RABBIT DOWN DRILL STRING, POH, STAND BACK BHA 04:30 - 06:00 1.50 11 A EVAL 3 RIG UP & RIH WITH SCHLUMBERGER WIRELINE LOGGING TOOLS: FROM BOTTOM TO TOP = HOLE FINDER, RESISTIVITY TOOL, KNUCKLE JOINT, DENSITY, NEUTRON TOOLS (PLATFORM EXPRESS ASSY.) WE RAN 3 - 6.88" STAND OFFS ON BOTTOM TOOL 4/10/2001 06:00 - 10:30 4.50 11 A EVAL 3 LOG WITH SCHLUMBERGER PLATFORM EXPRESS. TOOL WOULD NOT PASS 13200'. 10:30 - 17:00 6.50 11 A EVAL 3 SECOND RUN DSI AND GR ALSO WOULD NOT PASS 13200'. 17:00 - 23:00 6.00 11 A EVAL 3 THIRD RUN UBI. WOULD NOT PASS 11200'. 23:00 - 02:30 3.50 06 H EVAL 3 PICK UP RERUN BIT AND RUN IN THE HOLE WITH CLEAN OUT ASSEMBLY. FILL PIPE. 02:30 - 03:30 1.00 09 EVAL 3 CUT AND SLIP DRILLING LINE AT SHOE. 03:30 - 06:00 2.50 06 H EVAL 3 RIH. WASH THROUGH SPOT AT 11200'. 13000' AT REPORT TIME. 4/11/2001 06:00 - 09:00 3.00 06 H CSGIN3 REAM 400' OF TIGHT HOLE TO BOTTOM. NO FILL. 09:00- 10:30 1.50 05 F CSGIN3 CIRCULATE 10:30 - 12:30 2.00 06 H CSGIN3 SHORT TRIP TO 13670'. CIRCULATE WHILE PULLING AND RUNNING. NO FILL. TIGHT. 12:30 - 15:00 2.50 05 F CSGIN3 CIRCULATE THE HOLE CLEAN. MANY FINE CUTTINGS. 15:00 - 16:30 1.50 06 H CSGIN3 SHORT TRIP TO 13175'. HOLE CONDITIONS IMPROVING. 16:30 - 19:00 2.50 05 F CSGIN3 CIRCULATE AND SWEEP WITH HI-VIS PILL. 19:00-20:00 1.00 06 H CSGIN3 SHORTTRIP TO 13700'. HOLE IN GOOD SHAPE. 20:00 - 20:30 0.50 05 F CSGIN3 SPOT HI DENSITY - HI VIS PILL 20:30 - 03:30 7.00 06 H CSGIN3 POH WITH STIFF WIPER ASSEMBLY. DROP 2.5" DRILL PIPE RABBIT AT SHOE. PUMP DRY JOB. HOLE IN GOOD SHAPE. 03:30 - 06:00 2.50 14 E CSGIN3 RIG TO RUN CASING. CHANGE PIPE RAMS TO 7 5/8". 4/12/2001 06:00 - 07:00 1.00 14 B CSGIN3 TEST 7 5/8" RAM DOOR SEALS. SET WAER BUSHING. 07:00 - 10:30 3.50 12 B CSGIN3 RIG TO RUN 7 5/8" LINER. 10:30 - 21:00 10.50 12 B CSGIN3 RUN 7 5/8" LINER. 21:00 - 22:00 1.00 12 B CSGIN3 RIG DOWN TOOLS. Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 9 of 17 Operations Summa Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: ,Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Phase Description of Operations Date From-To[Hours Code IcS(~dbe'.. .................. .__J ..................................................................................................... ............................................................................. ............................................ ~ ............................................. / ........ : ................... ~ .............. - ............... ~'-'"'~' I 1.00 12 lB CSGIN3 MAKE UP BAKER LINER HANGER. 4/12/2001 22:00 - 23:00 I 23:00 - 01:00 2.00 05 F CSGIN3 CIRCULATE LINER VOLUME. 6 B/M -1150PSl. 01:00 - 03:30 2.50 12 B CSGIN3 ~RUN IN TO CASING SHOE. 03:30 - 04:00 0.50 05 F CSGIN3 FILL PIPE. BREAK CIRCULATION. UP WT 210K. DN 160K. 04:00 - 06:00 2.00 12 B CSGIN3 RUN LINER. 12000' AT REPORT TIME WITH NO PROBLEMS. 4/13/2001 06:00 - 07:30 1.50 12 B CSGIN3 RIH WITH 7 5~8" CASING. 07:30 - 08:00 0.50 12 B CSGIN3 MAKE UP CEMENT HEAD. 08:00 - 08:30 0.50 12 B CSGIN3 CIRCULATE 15' TO BOTTOM 08:30- 11:00 2.50 12 B CSGIN3 CIRCULATE BOTTOMS UP PLUS. 1150 PSI AT 6 B/M 11:00 - 12:00 1.00 12 B CSGIN3 DROP BALL AND PUMP TO BOTTOM. 12:00 - 12:30 0.50 12 B CSGIN3 SET LINER HANGER WITH 2000PSI. ~ RELEASE HR TOOL WITH 2800 PSI. SHEAR BALL SEAT WITH 4000 PSI. 12:30 - 16:00 3.50 12 C CSGPRO SAFETY MEETING. PUMP PREFLUSH, SPACER AND 15.8# CEMENT. DISPLACE WITH CEMENT UNIT. BUMP PLUG AND CHECK FLOATS. 16:00 - 17:00 1.00 12 D CSGIN3 SET LINER TOP PACKER AND TEST ANNULUS TO 3000 PSI. 17:00 - 06:00 13.00 06 J CSGIN3 SETASlDE 5" HWDP. LAY DOWN EXCESS 5" DRILL PIPE. POH AND LAY DOWN LINER RUNNING TOOL. LAY DOWN AND SORT DRILL PIPE NEEDING HARD BANDING. LAY DOWN 8 1/2" BHA. UNLOAD WORK BOAT WITH 3 1/2" DRILL PIPE AND DRLG TOOLS. 4/14/2001 06:00 - 10:30 4.50 25 UNLOAD WORK BOAT WITH 6 3/4" DRILLING TOOLS AND 3 1/2" DRILL PIPE. TEST CHOKE MANIFOLD AND SAFETY VALVES TO 4000 PSI. 10:30 - 18:30 8.00 06 FINISH STANDING BACK 5" DRILL PIPE. I LAY DOWN EXCESS DRILL PIPE. SORT JOINTS NEEDING HARD BANDING. 18:30 - 20:30 2.00 15 CHANGE BOTTOM RAMS TO 3 1/2". PULL WEAR RING. SET TEST PLUG. 20:30 - 01:30 5.00 15 TEST BOP TO 4000 PSI. ANNULAR TO 3500 PSI. 01:30 - 03:30 2.00 27 DRLPRO PICK UP BHA AND BIT # 12. 03:30 - 06:00 2.50 06 A DRLPRO STRAP, RABBIT AND PICK UP 3 1/2" DRILL PIPE. 4/15/2001 06:00 - 15:00 9.00 26 DRLPRO PICK UP 3 1/2" DRILL PIPE. 15:00 - 15:30 0.50 07 DRLPRO RIG SERVICE. 15:30 - 16:00 0.50 05 DRLPRO CIRCULATE. CHANGE PIPE HANDLING TOOLS. 16:00 - 20:00 4.00 06 DRLPRO RIH WITH 5" DRILL PIPE. TAG UP AT 14175'. 20:00 - 21:00 1.00 02 D DRLPRO CLEAN OUT TO LANDING COLLAR AT 14234'. 21:00 - 22:30 1.50 05 DRLPRO CIRCULATE HOLE CLEAN. 22:30 - 23:00 0.50 25 DRLPRO TEST CASING TO 4000 PSI. GOOD TEST. 23:00 - 03:30 4.50 02 D DRLPRO DRILL OUT CEMENT AND FLOAT EQUIPMENT. 03:30 - 06:00 2.50 02 A DRLPRO DRILL AHEAD WITH BIT # 12. 4/16/2001 06:00 - 06:30 0.50 02 A DRLPRO DRILLING WITH BIT # 12. 06:30- 08:30 2.00 05 A DRLPRO CIRCULATE. 08:30 - 09:30 1.00 25 DRLPRO FORMATION INTEGRITY TEST TO 10.5 PPG. GOOD TEST. 09:30- 19:30 10.00 02 A DRLPRO DRILL AHEAD. 19:30 - 21:30 2.00 05 I DRLPRO ClRCUATE SAMPLES. CHECK FOR CORE POINT. 21:30 - 22:30 1.00 02 A DRLPRO DRILL TO CORE POINT. 22:30 - 01:00 2.50 05 I DRLPRO CIRCULATE SAMPLES. 01:00 - 01:30 0.50 06 A DRLPRO PULL INTO SHOE. PUMP DRY JOB. 01:30 - 06:00 4.50 06 J DRLPRO POH TO PICK UP CORE BARREL. 4/17/2001 06:00 - 08:30 2.50 06 A DRLPRO POH WITH BHA #18, BIT#RR 12 08:30 - 14:00 5.50 27 DRLPRO LAY DOWN BHA, PICK UP CORE BHA #1, (BHA#19), SPACE OUT Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 10 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 ,Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End' Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date ~ From - To Hours Code~cSoUdbe Phase Description of Operations . i 4/17/2001 08:30 - 14:00 5.501 27 i i DRLPRO INNER CORE BARRELS, SET MULTI SHOT SURVEY TOOL, (ESS II TOOL), RIH WITH BHA 14:00 - 17:00 3.00 06 D DRLPRO RIH WITH 3 1/2" DRILL PIPE 17:00 - 18:00 1.00 09 DRLPRO CUT & SLIP 90' OF DRILLING LINE 18:00 - 18:30 0.50 07 DRLPRO SERVICE RIG & TOP DRIVE 18:30 - 21:00 2.50 04 A DRLPRO RIH 21:00 - 21:30 0.50 03 B DRLPRO WASH FROM 14400' TO 14420' 21:30 - 02:00 4.50 04 A DRLPRO DRILL 2 5~8" CORE SAMPLES WITH 6 3/4" BIT FROM 14420' TO 14440' 02:00 - 03:00 1.00 06 D DRLPRO NO PENETRATION RATE,CORE BARREL APPEARS TO BE JAMMMED, CHECK FLOW, POH TO 14310', DROP PUMP OUT SUB DART, PUMP DRY JOB 03:00 - 06:00 3.00 06 D DRLPRO POH WITH BHA #19, CORE BHA #1, BIT #13 4/18/2001 06:00 - 09:30 3.50 06 D DRLPRO POH WITH BHA#19, CORE BHA#1,6 3/4" BIT#13 09:30 - 11:30 2.00 27 DRLPRO STAND BACK DRILL COLLARS, LAY DOWN, CUT & BOX UP 14.2' OF 2 5/8" CORE SAMPLES, RETRIEVE & DOWN LOAD MULTISHOT SURVEY TOOL, REINSTALL 11:30 - 15:00 3.50 27 DRLPRO PICK UP INNER CORE BARREL & SPACE OUT, RIH WITH BHA & 3 1/2" HT DRILL PIPE 15:00 - 15:30 0.50 07 DRLPRO SERVICE RIG & TOP DRIVE 15:30 - 18:00 2.50 06 D DRLPRO RIH WITH BHA#20, (CORE BHA#2), BIT #13 RR1 18:00 - 18:30 0.50 03 B DRLPRO WASH FROM 14410' TO 14440' 18:30 - 00:30 6.00 04 A DRLPRO CORE FROM 14440' TO 14475 = 35', APPEARS CORE BARREL HAS JAMMED, NO PENETRATION RATE 00:30 - 01:30 1.001 06 D DRLPRO CHECK FLOW, POH TO 7 5/8" CASING SHOE, DROP SHEAR SUB DART, PUMP DRY JOB 01:30 - 06:00 4.50 06 D DRLPRO POH WITH CORE BHA #2 4/19/2001 06:00 - 07:30 1.50 06 D DRLPRO POH WITH BHA #20,(CORE BHA #2), BIT#13RR1 07:30 - 10:30 3.00 27 DRLPRO STAND BACK DRILL COLLARS, LAY DOWN MULTISHOT TOOL, DOWN LOAD SURVEYS, LAY DOWN 35' OF 2 5~8" CORE, STRAP, CUT & BOX UP SAMPLES. MAKE UP NEW BIT & ORIENT MULTISHOT TOOL, PICK UP & SPACE OUT INNER CORE BARREL, RIH WITH BHA 10:30 - 14:00 3.50 06 D DRLPRO RIH WITH 3 1/2" HT 38 DRILL PIPE 14:00 - 14:30 0.50 DRLPRO SERVICE RIG & TOP DRIVE 14:30 - 16:30 2.00 06 D DRLPRO RIH 16:30 - 17:00 0.50 03 B DRLPRO WASH FROM 14455' TO 14475', SURVEY 17:00 - 23:30 6.50 04 A DRLPRO CORE 6 3/4" HOLE, (2 5/8" CORE SAMPLES) FROM 14475' TO 14537' = 62', (FULL CORE BARREL) 23:30 - 01:00 1.50 06 D DRLPRO BACK REAM OFF BOTTOM 25' (TIGHT SPOTS), POH TO 7 5/8" SHOE, CHECK FLOW, DROP PUMP OUT SUB DART, PUMP DRY JOB 01:00 - 06:00 5.00 06 D DRLPRO POH WITH BHA #21,(CORE BHA #3), BIT #14 4/20/2001 06:00 - 12:00 6.00 27 DRLPRO STAND BACK DRILL COLLARS, LAY DOWN FULL RECOVERY 2 5/8" CORE OF 62', LAY DOWN MULTISHOT TOOL & DOWN LOAD SURVEYS, MAKE UP & SPACE OUT NEW INNER CORE BARREL, REINSTALL MULTI SHOT TOOL, RIH WITH BHA # 22,(CORE BHA #4) & BIT#14 RR#1 12:00 - 12:30 0.50 07 DRLPRO SERVICE RIG & TOP DRIVE 12:30 - 13:30 1.00 06 D DRLPRO RIH WITH 3 1/2" HT38 DRILL PIPE 13:30 - 15:00 1.50 09 DRLPRO CUT & SLIP 90' OF DRILLING LINE 15:00- 17:00 2.00 06 D DRLPRO RIH 17:00 - 18:30 1.50 03 B DRLPRO WASH & REAM FROM 14437' TO 14537' T.D. Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 11 of.17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit#2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DP, LG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date ~ From - To/ HoursI Code/(~(~dbe' Phase Description of Operations 4/20/2001 !18:30 - 23:00' 4.50 04 iA DRLPRO i CORE 6 3/4" HOLE, FROM 14537' TO 14558' 23:00 - 23:30 0.50 06 ID DRLPRO1APPEARS TO HAVE JAMMED CORE BARREL, POH TO 7 5/8" SHOE 23:30 - 04:00 4.50 06 D i DRLPRO CHECK FLOW, DROP PUMP OUT SUB DART, PUMP DRY JOB, POH WITH BHA #22, BIT #14 RR1 04:00 - 05:00 1.00 08 E DRLPRO WORK ON TOP DRIVE JAMMED BULL WHEEL ON LINK TILT (POSSIBLE HYDRAULIC PUMP PROBLEM) 05:00- 06:00 1.00 06 D DRLPRO POH 4/21/2001 06:00 - 07:00 1.00 06 D DRLPRO POH W/BHA #22, (CORE BHA fh4), BIT #14, RR1 07:00 - 12:00 5.00 27 DRLPRO STAND BACK DRILL COLLARS, LAY DOWN MULT SHOT TOOL (DOWN LOAD) & 21' OF 2 5/8" CORE, REINSTALL MULT SHOT (ORIENT) & CORE BARREL (SPACE OUT), RR BIT, RIH WITH BHA 12:00 - 14:00 2.00 06 D DRLPRO RIH WITH 3 1/2" HT 38 DRILL PIPE ON BHA #23, (CORE BHA #5), BIT #14 RR2 14:00 - 15:00 1.00 07 DRLPRO SERVICE RIG & TOP DRIVE, ATTEMPT TO WORK ON LINK TILT 15:00- 18:00 3.00 06 D DRLPRO RIH 18:00 - 18:30 0.50 03 B DRLPRO WASH & REAM FROM 14533' TO 14558' 18:30 - 23:00 4.50 04 A DRLPRO CORE 6 3/4" HOLE, FROM 14558' TO 14567' 23:00 - 23:30 0.50 06 D DRLPRO CHECK FLOW, POH TO 7 5/8" SHOE 23:30 - 00:30 1.00 05 E DRLPRO CHECK FLOW, DROP PUMP OUT SUB DART, PUMP DRY JOB 00:30 - 06:00 5.50 06 D DRLPRO POH WITH BHA #23, (CORE BHA #5), BIT #14 RR2 4/22/2001 06:00 - 09:00 3.00 06 D DRLPRO POH WITH BHA #23, (CORE BHA #5), BIT #14 RR2 09:00 - 13:00 4.00. 27 DRLPRO STAND BACK DRILL COLLARS, LAY DOWN 2 5/8" CORE SAMPLE = 7' & MULTI SHOT SURVEY TOOL, DOWN LOAD SAME, MAKE UP NEW CORE BIT, STAND BACK IN DERRICK 13:00 - 16:00 3.00 DRLPRO TEST BOPE FROM 350 PSI TO 4000 PSI, HYDRIL BAG FROM 350 PSI TO 3500 PSI, PERFORM KOOMEY TIME TEST & COMBUSTIBLE ALARMS TEST, REINSTALL WEAR RING 16:00 - 18:00 2.00 27 DRLPRO MAKE UP ROTARY ASSY. & RIH WITH BHA #24, BIT 12 RR2 18:00 - 22:00 4.00 06 A DRLPRO RIH 22:00 - 23:30 1.50 09 DRLPRO CUT & SLIP 75' OF DRILL LINE 23:30 - 04:00 4.50 06 A DRLPRO RIH, TO 7 5/8" SHOE 04:00 - 04:30 0.50 05 A . DRLPRO FILL DRILL PIPE, CIRC & COND (SHEAR O.B.M.) MAKE UP TOP DRIVE BLOWER HOSE 04:30 - 06:00 1.50 03 A DRLPRO WASH & REAM FROM 14325' TO 14515' (14567' IS 6 3/4" HOLE T.D.) 4/23/2001 06:00 - 07:00 1.00 03 A DRLPRO WASH & REAM FROM 14325' TO 14567' WITH ROTARY BHA #24 BIT #12 RR2, (TIGHT HOLE) 07:00 - 14:00 7.00 02 A DRLPRO DRILL AHEAD FROM 14567' TO 14594', FOREST OIL GEOLOGIST OBSERVED SAND ZONE AT 14594', CALLED 14594' CORE POINT 14:00 - 18:30 4.50 05 A DRLPRO CIRC BOTTOMS UP TO CONFIRM FORMATION, PUMP SWEEP AROUND 18:30 - 19:00 0.50 06 A DRLPRO DROP MULTI SHOT SURVEY TOOL, CHECK FLOW, POH TO 7 5/8" SHOE i19:00 - 19:30 0.50 05 A DRLPRO DROP PUMP OUT SUB DART, PUMP DRY JOB 19:30 - 02:30 7.00 06 A DRLPRO POH WITH ROTARY BHA #24, BIT #12 RR2 !02:30 - 05:00 2.50 27 DRLPRO POH WITH BHA, LAY DOWN & DOWN LOAD MULIT SHOT SURVEY TOOL, BREAK OFF BIT 05:00 - 05:30 0.50 07 DRLPRO CLEAN RIG FLOOR, SERVICE RIG & TOP DRIVE 05:30 - 06:00 0.50 27 DRLPRO MAKE UP & RIH WITH BHA #25, (CORE BHA #6), BIT #15 4/24/2001 06:00 - 12:00 6.00 06 D DRLPRO RIH FOR CORE # 6. 12:00 - 13:00 1.00 07 DRLPRO RIG SERVICE. 13:00- 15:30 2.50 06 D DRLPRO RIH TO BOTTOM. 15:30 - 18:00 2.50 06 D DRLPRO PULL BACK TO SHOE. UNPLUG DRILL STRING. RIH. 18:00 - 05:00 11.00 04 A DRLPRO CORE WITH BIT # 15 ( CORE # 6 - 27') Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 12 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date [ From -To Hours [ Code Code~_Sub Phase Description of Operations 4/24/2001 05:00 - 06:00 1.00 06 i D ' DRLPRO i POH TO SHOE AT 14320'. ONE TIGHT SPOT AT 14594'. 4/25/2001 .06:00 06:30 0.50 06 D DRLPRO I AT 7 5~8" SHOE PUMP DRY JOB. ~06:30 - 14:00 7.50 06 D I DRLPRO POH WITH CORE # 6. 14:00 - 14:30 0.50= 06 D DRLPRO RECOVER # 6 CORE. 27' OF CORE 100% RECOVERY. 14:30 - 22:00 7.50 06 D DRLPRO RIH WITH CORE # 7 TO SHOE AT 14320'. 22:00 - 23:00 1.00 06 D DRLPRO WASH TO BOTTOM. 23:00 - 06:00 7.00 04 A DRLPRO ON BOTTOM CORING. 4/26/2001 06:00 - 06:30 0.50 06 D DRLPRO POH TO SHOE WITH CORE # 7. 06:30 - 07:00 0.50 06 D DRLPRO PUMP DRY JOB. 07:00- 13:30 6.50 06 D DRLPRO POH. 13:30 - 15:30 2.00 06 D DRLPRO LAY DOWN CORE # 7. RECOVERED 52' OF 53' CUT. 15:30 - 22:00 6.50 06 D DRLPRO RIH WITH CORE # 8 TO SHOE AT 14320'. 22:00 - 23:30 1.50 09 DRLPRO CUT DRILLING LINE. 23:30 - 03:00 3.50 08 I E DRLPRO REPAIR TOP DRIVE PIPE HANDLER. 03:00 - 05:00 2.00 06 D DRLPRO WASH TO BOTTOM. ONE TIGHT SPOT AT 14644'. 05:00 - 06:00 1.00 04 A DRLPRO CORE AHEAD WITH # 7. 4/27/2001 06:00 - 09:00 3.00 04 A DRLPRO CORE # 8. TOTAL FOOTAGE 15'. 09:00 - 09:30 0.50 06 D DRLPRO POH TO SHOE. NO PROBLEMS. 09:30 - 10:00 0.50 06 D DRLPRO PUMP DRY JOB. 10:00- 17:30 7.50 06 D DRLPRO POH. 17:30 - 19:00 1.50 06 D DRLPRO LAY DOWN CORE # 8. RECOVERED 14' 9". BIT WAS RUNG OUT. 19:00 - 19:30 0.50 07 DRLPRO RIG SERVICE. 19:30 - 03:00 7.50 11 A DRLPRO LOG WITH SCHLUMBERGER QUAD COMBO. 03:00 - 06:00 3.00 06 A DRLPRO MAKE UP BHA. RIH WITH BIT # 17. 4/28/2001 06:00 - 11:00 5.00 06 A DRLPRO TRIP IN THE HOLE WITH BIT # 17 11:00 - 12:00 1.00 06 A DRLPRO BREAK CIRC AT SHOE. ATTACH BLOWER HOSE. 12:00 - 13:30 1.50 06 A DRLPRO RIH TO BOTTOM. BREAK CIRCULATION. 13:30 - 03:00 13.50 02 A DRLPRO DRILLING AHEAD WITH BIT # 17. 03:00 - 04:00 1.00 08 B DRLPRO POH TO SHOE FOR RIG REPAIRS. 04:00 - 06:00 2.00 08 B DRLPRO RIG REPAIRS. BEGIN REPLACING TOP DRIVE TRACTION MOTOR. 4/29/2001 06:00 - 13:30 7.50 08 B DRLPRO DISASSEMBLE TOP DRIVE. 13:30 - 20:00 6.50 08 B DRLPRO REMOVE COMPONETS FROM FAILED TRACTION MOTOR. DRESS NEW TRACTION MOTOR. SET IN PLACE. 20:00 - 06:00 10.00 08 B DRLPRO MOUNT TRACTION MOTOR ON TOP DRIVE. 4/30/2001 06:00 - 15:00 9.00 08 B DRLPRO INSTALL REBUILT TOP DRIVE TRACTION MOTOR. UNIT DOES NOT OPERATE. 15:00 - 18:30 3.50 08 B DRLPRO REMOVE TRACTION MOTOR FROM RIG. 18:30 - 06:00 11.50 08 B DRLPRO OVERHAUL TRACTION MOTOR. 5/1/2001 06:00 - 15:30 9.50 08 B DRLPRO CONTINUE MONITORING WELL & CIRC PERIODICALLY WHILE REPAIRING TOP DRIVE TRACTION MOTOR, COMBINE PARTS FROM 2 - TRACTION MOTORS, CHANGE OUT ARMATURES & COMPONENTS, PRE - HEAT NEW PINION GEAR FOR INSTALLATION ON MOTOR DRIVE, TEST TRACTION MOTOR & SET BRUSHES, CHECK BEARINGS 15:30 - 19:00 3.50 08 B DRLPRO PICK & SPOT WITH CRANE, STAB & INSTALL MOTOR ON TOP DRIVE, SHIM & ALIGN GEAR LASH, TORQUE MOUNTING BOLTS, INSTALL SAFETY WIRE & KEEPERS 19:00 - 21:00 2.00 08 B DRLPRO INSTALL TORQUE BOOST, SPARK ARRESTOR, HYDRAULIC & ELECT. LINES, FILL GREASE BLOCKS 21:00 - 01:00 4.00 08 B DRLPRO INSTALL GUARDS, SPACERS, KEEPERS, SAFETY WIRES, 75 / 90 GEAR OIL, CLEAN UP & WIPE DOWN FOR DETECTING LEAKS, INSPECT BRAKES & LINKAGE. (PINION ALIGMENT TOE IN SHIM Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 13 of 17 Operations Sumnaa Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 5/1/2001 21:00-01:00] 4.00 08 B DRLPRO TO .001, PINION BACKLASH .015 01:00 - 02:00 1.00 08 B DRLPRO PERFORM FUNCTION TEST OF TOP DRIVE TRACTION MOTOR & TOP DRIVE, INGAGE TORQUE BOOST TO BREAK OUT OF DRILL STRING & SHEARED THE DOGS ON THE TORQUE BOOST & BEARING FAILURE DUE TO CROSSED HYDRAULIC HOSES 02:00 - 06:00 4.00 08 B DRLPRO REMOVE & REPAIR TORQUE BOOST COMPONENT 5/2/2001 06:00 - 12:30 6.50 08 B DRLPRO :REPAIR TORQUE BOOST ON TOP DRIVE 12:30 - 13:00 0.50 08 B DRLPRO RIH, WASH FROM 14692' TO 14727', GOOD TRIP, NO FILL 13:00- 15:00 2.00 02 A DRLPRO DRILL WITH BHA #28, BIT#17, FROM 14727' TO 14720' 15:00 - 15:30 ~ 0.50 05 A DRLPRO CIRC BOTTOMS UP (THICK HEAVY MUD FROM BOTTOMS UP) 15:30 - 22:30 ' 7.00 02 A DRLPRO DRILL AHEAD FROM 14740' TO 14800' 22:30 - 01:30 3.00 05 A DRLPRO CIRC SWEEP AROUND & CATCH BOTTOMS UP SAMPLE TO VERIFY CORE POINT 01:30 - 02:30 1.00 06 A DRLPRO CHECK FLOW, POH TO 7 5/8" CASING SHOE, GOOD TRIP 02:30 - 03:00 0.50 06 A DRLPRO DROP PUMP OUT SUB DART, CHECK FLOW, PUMP PILL, REMOVE BLOWER HOSE (HIGH WINDS) 03:00 - 06:00 3.00 06 A DRLPRO POH WITH ROTARY BHA #28, BIT #17 5/3/2001 06:00 - 12:00 6.00 06 A DRLPRO POH WITH BIT # 17. 12:00 - 17:00 5.00 15 A DRLPRO TEST BOP. AOGCC WAIVED WITNESS. 17:00 - 22:30 5.50 11 F DRLPRO LOG WITH SCHLUMBERGER. GR, CL AND TEMP TOOL. LOG FROM SURFACE TO 9000'. MAKE BASE LINE PASS. 22:30 - 04:30 6.00 25 DRLPRO INJECT 1000 BBLS SEA WATER AT 3 BBL/MIN. INTO 9 5/8" X 13 3/8" ANNULUS. 04:30 - 06:00 1.50 11 F DRLPRO LOG WITH SCHLUMBERGER TEMPERATURE TOOL. 5/4/2001 06:00 - 09:00 3.00 11 F DRLPRO RIH, PERFORM POST INJECTION TEST LOG FROM SURFACE TO 7000', POH WITH SCHLUMBERGER WlRELINE TEMPERTURE LOG, RIG DOWN WlRELINE EQUIPMENT 09:00 - 11:00 2.00 27 DRLPRO MAKE UP CORE BHA #9 & RIH 11:00 - 13:30 2.50 06 D DRLPRO RIH WITH 3 1/2 HT 38 DRILL PIPE 13:30 - 15:30 2.00 06 D DRLPRO RIH WITH 5" DRILL PIPE, BREAK ClRC & FILL PIPE @ 5000' INTERVALS 15:30 - 20:00 4.50 03 B DRLPRO FILL PIPE @ 7 5~8" SHOE, ATTACH BLOWER HOSE, WASH & REAM FROM 14325' TO 14800' (HOLE IN GOOD SHAPE) 20:00 - 06:00 10.00 04 A DRLPRO BEGIN CORING 6 3/4" HOLE WITH BHA #29 (CORE BHA# 9) BIT #18, FROM 14800' TO 14815' 5/5/2001 06:00 - 22:00 16.00 04 A DRLPRO DRILL 2 5/8" CORE SAMPLE IN 6 3/4" HOLE, WITH BHA #29 (CORE BHA #9), BIT #18 FROM 14815' TO 14844' 22:00 - 23:00 1.00 06 D DRLPRO BIT WEIGHT WOULD NOT DRILL OFF, LAY DOWN PUP JOINT & 2 - JOINTS OF 5" DRILL PIPE, CHECK FLOW, POH TO 7 5/8" SHOE (GOOD TRIP) 23:00 - 00:00 1.00 05 E DRLPRO CHECK FLOW, PUMP DRY JOB, REMOVE BLOWER HOSE 00:00 - 06:00 6.00 06 D DRLPRO POH WITH BHA #29 (CORE BHA #9) BIT #18 5/6/2001 06:00 - 09:30 3.50 27 DRLPRO POH WITH BHA#29, (CORE BHA# 9) BIT #18, LAY DOWN 43 1/2' OF CORE, MAKE UP NEW BIT & SPACE OUT INNER CORE BARREL & MULTISHOT SURVEY TOOL, RIH WITH CORE BHA #10 09:30 - 12:00 2.50 06 D DRLPRO RIH TO 9000' 12:00 - 12:30 0.50 07 DRLPRO SERVICE RIG & TOP DRIVE, WHILE FILLING DRILL PIPE 12:30 - 14:30 2.00 06 D DRLPRO RIH, FILL DRILL PIPE @ 5000' INTERVALS, SHEAR MUD & ATTACH BLOWER HOSE @ 7 5/8" SHOE 14:30 - 15:00 0.50 03 B DRLPRO WASH & REAM TO BOTTOM, NO FILL (GOOD TRIP) 15:00 - 15:30 0.50 05 E DRLPRO CIRC., RECORD SLOW PUMP RATE & SURVEY 15:30 - 02:00 10.50 04 A DRLPRO DRILL 2 5/8" CORE IN 6 3~4" HOLE, FROM 14844' TO 14898' 02:00 - 03:00 1.00 06 D DRLPRO SURVEY, CHECK FLOW, POH TO 7 5~8" SHOE Printed: 712312001 9:42:56 AM ,,, FOREST OIL CORP. Page 14 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date 1 From -To Hours Code /Code~SUb Phase I Descnpbon' ' of Operabons' ~. 5/6/2001 103:00 - 03:30 , 0.50 05 I E ' DRLPRO CHECK FLOW, DROP PUMP OUT SUB DART, PUMP DRY JOB 03:30 - 06:00 ! 2.50 06 D DRLPRO POH W/BHA #30 (CORE BHA#10), BIT #19 5/7/2001 06:00- 09:30 ! 3.50 06 D DRLPRO POH WITH BHA#30 (CORE BHA #10) BIT #19 09:30 - 13:00 3.50 27 DRLPRO LAY DOWN & DOWN LOAD MULTISHOT SURVEY TOOL, RETRIEVE 53.7' OF CORE, MAKE UP NEW BIT, SPACE OUT NEW CORE BARREL & INSTALL MULTISHOT SURVEY TOOL, RIH WITH DRILL COLLARS & 3 1/2" HWDP 13:00 - 15:00 2.00 06 D DRLPRO RIH TO 8800', FILL DRILL PIPE, PERFORM BOPE DRILL 15:00 - 16:00 1.00 09 DRLPRO CUT & SLIP 104' OF DRILLING LINE 16:00 - 18:00 2.00 06 D DRLPRO RIH TO 14252', FILL DRILL PIPE 18:00 - 18:30 0.50 05 E DRLPRO CIRC & COND. SHEAR MUD, INSTALL BLOWER HOSE ON TOP DRIVE, SERVICE RIG 18:30 - 19:30 1.00 06 D DRLPRO RIH TO 14795', WASH & REAM TO BOTTOM, (GOOD TRIP), SPACE OUT PROPERLY FOR CORE RUN 19:30 - 23:00 3.50 04 A DRLPRO DRILL 2 518" CORE IN 6 314" HOLE FROM 14898' TO 14912' 23:00 - 00:30 1.50 06 D DRLPRO BREAK OFF CORE, CHECK FLOW, POH TO 7 5~8" SHOE 00:30 - 01:00 0.50 05 E DRLPRO CHECK FLOW, DROP PUMP OUT SUB DART, PUMP DRY JOB 01:00 - 06:00 5.00 06 D DRLPRO POH WITH BHA #31 (CORE BHA#11), BIT #20 5/8/2001 06:00 - 09:30 3.50 06 D DRLPRO POH AND LAY DOWN CORE # 11. 09:30 - 10:00 0.50 07 DRLPRO RIG SERVICE. 10:00 - 11:30 1.50 08 DRLPRO REPAIR RIG. TOP DRIVE OILAND PINION GEAR. 11:30 - 17:30 6.00 06 D DRLPRO DRESS CORE #12. RIH TO BOTTOM. 17:30 ~ 18:00 0.50 08 B DRLPRO PULL BACK INTO SHOE FOR RIG REPAIRS. 18:00 - 20:00 2.00 08 B DRLPRO REPAIR RIG. REMOVE TORQUE BOOST FROM TOP DRIVE. 20:00 - 20:30 0.50 08 B DRLPRO TRIP BACK TO BOTTOM. 20:30 - 06:00 9.50 04 A DRLPRO CORE AHEAD FROM 14912' TO 14926'. 5/9/~001 06:00 - 13:00 7.00 04 A DRLPRO CORE # 12. 13:00- 19:00 6.00 06 D DRLPRO POH. 19:00- 22:30 3.50 06 J DRLPRO EMPTY CORE BARREL. DRESS CORE BARREL. 22:30 - 03:30 5.00 06 D DRLPRO RIH TO SHOE AT 14320'. 03:30 - 04:30 1.00 09 DRLPRO CUT AND SLIP DRILLING LINE. 04:30 - 05:00 0.50 07 DRLPRO RIG SERVICE. 05:00 - 06:00 1.00 08 B DRLPRO REPAIR TOP DRIVE AT SHOE. 5/10/2001 06:00 - 09:30 3.50 08 B DRLPRO REPAIR TOP DRIVE AT 7 5/8" SHOE. 09:30 - 10:00 0.50 06 D DRLPRO RIH TO BOTTOM. NO HOLE PROBLEMS. 10:00- 16:30 6.50 04 A DRLPRO CORING 16:30 - 00:00 7.50 06 D DRLPRO POH 00:00 - 01:30 1.50 06 D DRLPRO LID CORE. RECOVERED 33'. STAND BACK TOOLS. 01:30 - 06:00 4.50 15 A DRLPRO PRESSURE TEST BOP. 5/11/2001 06:00 - 06:30 0.50 15 A FINISH BOP TEST. 06:30 - 13:00 6.50 06 D RIH WITH CORE # 14. 13:00 - 14:00 1.00 07 RIG SERVICE AT SHOE. 14:00 - 14:30 0.50 06 D RIH TO BOTTOM. 14:30 - 20:30 6.00 04 A CORING FRON 14968' TO 14978'. 20:30 - 06:00 9.50 06 D POH. LAY DOWN CORE # 14. DRESS CORE BARREL. RECOVERED 9.7'. 5/12/2001 06:00 - 11:00 5.00 06 D DRLPRO RIH WITH CORE BARREL # 15. 11:00 - 12:00 1.00 07 DRLPRO CHANGE OIL AND FILTER IN TOP DRIVE AT 7 5/8" SHOE. 12:00 - 12:30 0.50 07 DRLIN3 RIG SERVICE. 12:30- 13:30 1.00 06 D DRLPRO RIH. 13:30 - 14:30 1.00 06 D DRLPRO WASH AND REAM FROM 14911' TO BOTTOM. NO FILL. 14:30 - 21:30 7.00 04 A DRLPRO CUT CORE # 15 FROM 14978' TO 15000'. 21:30 - 04:00 6.50 06 D DRLPRO POH WITH CORE BARREL. I Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 15 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End' Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date ' From -To/ Hours Code Sub PhaseI Description of Operations [ Code 5/12/2001 04:00 - 06:00 2.00 06 !D DRLPRO LAY DOWN CORE # 15. 100% RECOVERY. 5/13/2001 06:00 - 07:30 1.50 06 ID DRLPRO DRESS CORE BARREL # 16. LOAD SURVEY TOOL. 07:30 - 12:30 5.00 06 D DRLPRO RIH TO SHOE AT 14320'. 12:30 - 14:30 2.00 09 ~ DRLPRO CUT OFF 350' OF DRILLING LINE. 14:30 - 15:30 1.00 07 ] DRLPRO RIG SERVICE. SERVICE TOP DRIVE. 115:30 - 16:30 1.00 06 D DRLPRO RIH. 16:30 - 17:00 0.50 06 D DRLPRO WASH AND REAM 25' TO BOTTOM. 17:00 - 03:30 10.50 04 A DRLPRO CORE FROM 15000' TO 15047'. 03:30 - 06:00 2.50 06 D DRLPRO TRIP OUT WITH CORE # 16. 5/14/2001 .06:00 - 10:00 4.00 06 :D DRLPRO POH WITH CORE # 16. 10:00 - 13:00 3.00 06 D DRLPRO LAY DOWN CORE. RETRIEVE SURVEY. DRESS CORE BARREL. 13:00 - 14:00 1.00 06 :D DRLPRO RIH WITH CORE # 17. 14:00 - 14:30 0.50 07 DRLPRO RIG SERVICE. 14:30 - 20:30 6.00 06 iD DRLPRO RIH BREAKING CIRCULATION. 20:30 - 21:00 0.50 03 I B DRLPRO WASH AND REAM FROM 15020' TO 15047'. NO FILL. 21:00 - 00:30 3.50 04 A DRLPRO CUT CORE # 17. TOTAL 13'. 00:30 - 06:00 5.50 06 ID DRLPRO POH WITH CORE # 17. 5/15/2001 06:00 - 07:30 1.50 06 i D DRLPRO POH WITH BHA #37 (CORE BHA#17), BIT#23 07:30 - 11:30 4.00 27 i DRLPRO LAY DOWN MULTI SHOT SURVEY TOOL & DOWN LOAD, RETRIEVE 12.7' OF CORE SAMPLE, INSTALL & SPACE OUT INNER : CORE BARREL, & RR BIT#23, RIH WITH BHA 11:30 - 12:00 0.50 07 DRLPRO SERVICE RIG & TOP DRIVE 12:00 - 14:00 2.00~ 06 D DRLPRO RIH WITH 3 1/2" DRILL PIPE, BHA#38 (CORE BHA#18) BIT# 23 RR1 14:00 - 14:30 0.50: 05 E DRLPRO CHANGE OVER TO 5" DRILL PIPE HANDLING TOOLS, CIRC & SHEAR O.B.M. 14:30 - 16:30 2.00 06 D DRLPRO RIH WITH 5" DRILL PIPE TO 7 5/8" SHOE 16:30 - 17:30 1.00 09 DRLPRO CUT & SLIP 75' OF DRILLING LINE 17:30 - 18:30 1.00 06 D DRLPRO RIH & WASH FROM 14942' TO 15036' 18:30- 19:00 0.50 03 B DRLPRO REAM FROM 15036' TO 15060' 19:00 - 03:00 8.00 04 A DRLPRO CORE 2 5/8" SAMPLES IN 6 3/4" HOLE FROM 15060' TO 15088' 03:00 - 04:00 1.00 03 . B DRLPRO CHECK FLOW, POH, PULLED TIGHT @ 15080', BACK REAM TO ' 15058', PULLED FREE 04:00 - 05:00 1.00 06 =D DRLPRO POH TO 7 5~8" SHOE, (GOOD TRIP FROM 15058' TO SHOE) 05:00 - 06:00 1.00 06 I D DRLPRO CHECK FLOW, DROP PUMP OUT SUB DART, PUMP DRY JOB, I POH WITH BHA#38 (CORE BHA#18), BIT# 23 RR1 5/1612001 06:00 - 11:00 5.00 06 D DRLPRO POH WITH BHA#38 (CORE BHA#18), BIT #23 RR1 11:00 - 13:30 2.50 27 DRLPRO LAY DOWN 27.5' OF CORE SAMPLE, LAY DOWN & DOWN LOAD MULTISHOT SURVEY TOOL, LAY DOWN MECHANICAL JARS & ~ ~ CORE BARREL ASSY. 13:30 - 14:00 0.50 07 i DRLPRO CLEAN RIG FLOOR, SERVICE RIG 14:00 - 15:00 1.00 27 DRLPRO MAKE UP MUD MOTOR ROTARY BHA, PICK UP HYDRAULIC JARS 15:00 - 21:00 6.00 06 A DRLPRO RIH WITH BHA #39 BIT #24, FILL PIPE @ 5000' INTERVALS, RIH TO 7 5/8" SHOE, SHEAR O.B.M. 21:00 - 21:30 0.50 06 A DRLPRO RIH TO 14389', (70' OUT OF SHOE), OBSERVED TIGHT HOLE CONDITIONS, PULLED LOOSE, MAKE UP TOP DRIVE 21:30 - 02:30 5.00 03 A DRLPRO REAM FROM 14389' TO 15088', OBSERVED HIGH TORQUE, EXCESSIVE CUTTINGS OVER SHAKER 02:30 - 06:00 3.50 02 A DRLPRO DRILL FROM 15088' TO 15100' 5/17/2001 06:00 - 19:30 13.50 02 A DRLPRO DRILL AHEAD WlTH BHA#39, BIT#24 FROM 15100' TO 15196' 19:30 - 20:00 0.50 07 DRLPRO SERVICE RIG & TOP DRIVE ON CONNECTION 20:00 - 03:00 7.00 02 A DRLPRO DRILL FROM 15196'TO 15254' 03:00 - 04:00 1.00 06 H DRLPRO CHECK FLOW, SHORT TRIP TO 7 5/8" SHOE, (TIGHT SPOTS @ 14435' TO 14400') I Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 16 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date I From - To Hours Code cSoUdbe' Phase ............................................. 1 ...................................... ! ..................... l ......................... 1 .....................---- ~ i ........ ................ '--I .......................................................................................................................... DescriPtion of Operations~ ............................................................................................ 15/17/2001 04:00 - 04:30 0.50107 ~ DRLPRO SERVICE RIG & CROWN SHEAVES 104:30 - 05:00 0.50 06 H DRLPRO RIH, (WORK THRU TIGHT HOLE @ 14400' & 14450') 05:00 - 06:00 1.00 02 A , DRLPRO DRILL AHEAD FROM 15254' TO 15260' 5/18/2001 06:00 - 16:00 10.00 02 A I DRLPRO DRILL 6 3/4" HOLE, WITH BHA #39, BIT #24 FROM 15260' TO 15325' 16:00 - 18:00 2.00 05 A DRLPRO ClRC & COND MUD & HOLE i 18:00 - 19:00 1.00 06 H DRLPRO CHECK FLOW, POH TO 7 5/8" SHOE, TIGHT SPOT @ 14427', RIH I FROM SHOE, WORK THRU TIGHT SPOT @ 14416' i 19:00 - 20:30 1.50 03 A DRLPRO REAM FROM 14410' TO 14460' 20:30 - 21:00 0.50 06 H DRLPRO RIH TO BOTTOM @ 15325', NO FILL 21:00 - 23:30 2.50 05 A DRLPRO CIRC & COND MUD & HOLE FOR LOGS 23:30 - 01:00 1.50 06 A DRLPRO CHECK FLOW, DROP SURVEY, POH TO 7 5/8" SHOE, OBSERVED TIGHT SPOT @ 14680' 01:00 - 01:30 0.50 05 A DRLPRO CHECK FLOW, DROP PUMP OUT SUB DART, PUMP DRY JOB 01:30 - 06:00 4.50 06 ~A DRLPRO POH WITH BHA #39, BIT #24, STRAP DRILL PIPE 5/19/2001 06:00 - 08:00 2.00 06 A DRLPRO POH WITH BHA #39, BIT #24, STRAP DRILL PIPE, (NO CORRECTION) 08:00 - 09:00 1.00 27 DRLPRO LAY DOWN / DOWN LOAD MULTISHOT SURVEY TOOL & BIT, STAND BHA BACK IN DERRICK 09:00 - 10:00 1.00 11 A EVALPR RIG UP SCHLUMBERGER UNIT & EQUIPMENT 10:00 - 15:00 5.00 11 A EVALPR RIH (RUN #1), & LOG 6 3~4" HOLE WITH QUAD COMBO WlRELINE TOOLS 15:00 - 20:00 5.00 11 A EVALPR RIH (RUN #2), LOG WITH UBI WlRELING TOOLS 20:00 - 03:00 7.00 11 A EVALPR RIH (RUN #3), LOG WITH RFT, TOOL FAILURE, POH 03:00 - 06:00 3.00 11 A EVALPR CHANGE OUT RFT TOOL & RIH, (RERUN #3) MAKE SETS IN 6 3/4" HOLE 5/20/2001 06:00 - 11:30 5.50 11 A EVALPR LOG 6 3/4" HOLE WITH SCHLUMBERGER WlRELINE, RFT (RERUN #3) 11':30 - 16:30 5.00 11 A EVALPR RIH, (RUN #4) LOG WITH CMR TOOL 16:30 - 17:00 0.50 11 A EVALPR BECAME STUCK @ 14920', WORK WlRELINE, WHILE MAKING ARRANGMENTS FOR FISHING PROCEDURE, PULLED FREE 17:00 - 21:00 4.00 11 A EVALPR CONTINUE LOGGING 6 3~4" HOLE WITH CMR TOOL 21:00 - 02:00 5.00 15 A EVALPR PULL WEAR BUSHING, TEST BOPE WITH A.O.G.C.C. REP AS WlTTNESS, TEST ANNULAR BAG F/350 PSI TO 3500 PSI, RAMS, i CHOKE MANIFOLD, MUD CROSS VALVES, TOP DRIVE VALVES & 3 1/2" & 5" FLOOR VALVES F/350 PSI TO 4000 PSI, TEST COMBUSTIBLE GAS ALARMS, RIG DOWN TEST EQUIP. INSTALL WEAR BUSHING 02:00 - 02:30 0.50 25 EVALPR CLEAN & ORGANIZE RIG FLOOR, PREP TO LAY DOWN MUD MOTOR ASSY. & MAKE UP STIFF CLEAN OUT BHA 02:30 - 06:00 3.50 27 EVALPR LAY DOWN MUD MOTOR ASSY. STRAP, PICK UP & MAKE UP STIFF 6 3/4" HOLE CLEAN OUT ASSY. WITH BIT #25 RR1 5/21/2001 06:00 - 12:00 6.00 06 A DRLPRO RIH WITH BHA #40, BIT #25 RR1 12:00 - 14:00 2.00 09 DRLPRO CUT & SLIP 100' OF DRILLING LINE @ 7 5/8" SHOE, SERVICE RIG 14:00 - 14:30 0.50 06 'A DRLPRO RIH, ENCOUNTER TIGHT SPOT @14610' & 14985' 14:30 - 17:30 3.00 03 'A DRLPRO REAM FROM 14980' TO 15325' 17:30 - 22:00 4.50 05 A DRLPRO CIRC BOTTOMS UP, CIRC HIGH VIS SWEEP AROUND (EXCESSIVE CUTTINGS OVER SHAKERS) 22:00 - 23:00 1.00 06 H DRLPRO CHECK FLOW, POH TO 7 5/8" CASING SHOE 23:00 - 23:30 0.50 06 H DRLPRO RIH (SLOW), GOOD HOLE CONDITIONS 23:30 - 03:30 4.00 05 A DRLPRO CIRC HI VIS SWEEP AROUND, SPOT 20 BBL HIGH VIS PILL ON BOTTOM 03:30 - 05:00 1.50 06 A DRLPRO CHECK FLOW, POH TO 7 5/8" SHOE, (GOOD HOLE CONDITIONS) Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 17 of 17 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG DRILLING Start: 2/23/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 , Date From -To J Hours Code Code'SUb Phase I Description of Operations 5/21/2001 i 05:00 - 06:00 1.00 06 A DRLPRO CHECKpREP ToFLOW'PoH DROP PUMP OUT SUB DART, DROP 5" RABBIT, I : Printed: 7/23/2001 9:42:56AM FOREST OIL CORP. Page 1 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date From - To Hours i Code i (~oUdDe Phase Description of .................................................................. t ................... ~ ........................ ~ .......... ............................... '--! ......................................................................................................................... Operations: ................................................ 5/22/2001 ' 06:00 - 15:00 ~. 9.00 06 A EVALPR i POH. LAY DOWN BHA. 15:00-22:00 I 7.00! 12 B ~CSGPRO PICK UP 51/2' LINER 22:00-22:30 0.50112 B CSGPRO ClRC LINER VOLUME. 22:30 - 06:00 7.50 12 B CSGPRO RIH WITH 5 1/2" LINER ON DRILL PIPE. DEPTH 10,000' AT REPORT TIME. 5/23/2001 06:00 - 09:30 3.50 12 B CSGPRO RUN LINER TO 7 5~8" SHOE FILLING PIPE EACH 10 STANDS 09:30 - 10:30 1.00 12 B CSGPRO RUN LINER TO BOTTOM WITHOUT ANY PROBLEMS 10:30 - 13:00 2.50 12 B CSGPRO CIRCUATE AND RECRIPROCATE PIPE AT 3.5 BBL/MIN 1000 PSI. 13:00 - 13:30 0.50 12 B CSGPRO RIG UP CEMENT HEAD. 13:30 - 14:00 0.50 12 B CSGPRO DROP BALL. SET HGR. RELEASE LINER. BLOW BALL. 14:00 - 17:30 , 3.50 12 C CSGPRO PUMP CMT AND DISPLACE. BUMPED PLUG TO 4000 PSI. 17:30 - 19:00 1.50~ 12 B CSGPRO SET LINER TOP PACKER. REVERSE CIRCULATE. 19:00 - 05:00 i 10.00 06 J CSGPRO LAY DOWN TOOLS AND POH. 05:00 - 06:00 1.00 06 J CSGPRO MAKE UP 6 3/4" BHA FOR CLEAN OUT RUN. 5/24/2001 06:00 - 13:00 7.00 06 H EVALPR MAKE UP 6 3~4" BIT WITH CASING SCRAPER AND RIH. 13:00 - 16:00 3.00 06 ~ H EVALPR WASH TO LINER TOP AT 14112'. CIRCULATE OUT CONTAMINATED MUD. NO CEMENT ON LINER TOP. 16:00 ~ 17:00 1.00 25 EVALPR TEST LINER TOP TO 4000 PSI. GOOD TEST. 17:00- 00:30 7.50 06 I J EVALPR POH. 00:30 - 03:30 3.00 27 J EVALPR LAY DOWN HWDP, 4 3/4" DRILL COLLARS AND 6 314" BIT. 03:30 - 06:00 2.50 27 EVALPR PICKING UP 4 3/4" BIT, CASING SCRAPER, 3 1/4" DC AND 2 7/8" DRILL PIPE. 5/25/2001 06:00 - 14:30 8.50 06 H EVALPR FINISH PICKING UP2 7/8" DRILL PIPE AND RUN IN THE HOLE. 14:30 - 15:30 1.00 09 EVALPR CUTAND SLIP DRILL LINE. 15:30 - 16:00 0.50 07 EVALPR RIG SERVICE AT 9 5/8" SHOE. 16:00- 19:00 3.00 06 H EVALPR RIH. TAG CEMENTAT 15210. 19:00 - 20:00 1.00 06 H EVALPR CLEAN OUT CEMENT TO LANDING COLLAR AT 15277'. 20:00- 00:00 4.00 05 F EVALPR CIRCULATE HOLE CLEAN. 00:00 - 01:00 1.00 25 EVALPR PRESSURE TEST CASING TO 4000 PSI. GOOD TEST. 01:00 - 06:00 5.00 05 EVALPR REVERSE CIRCULATE AT TD. 5/26/2001 06:00- 06:00 24.00 25 EVALPR CLEAN MUD PITS. REMOVE OIL BASE. 5/27/2001 06:00 - 15:00 9.00 25 EVALPR CLEAN OIL BASED MUD FROM PITS. 15:00 - 22:00 7.00 25 EVALPR BUILD 8.6# BRINE AND MIX SPACERS. 22:00 - 04:30 6.50 05 EVALPR REVERSE CIRCULATE. DISPLACE. 04:30 - 06:00 1.50 06 EVALPR POH. BEGIN LAYING DOWN DRILL PIPE. 5/28/2001 06:00 - 01:30 19.50 06 EVALPR POH WITH 4 3/4" BIT AND CASING SCRAPER. LAY DOWN 5" DRILL PIPE NEEDING HARDBANDING. STAND BACK 73 STANDS (6800') OF 5" DRILL PIPE. LAYDOWN 3 1/2" DRILL PIPE, 3 1/4" COLLARS, BIT AND SCRAPER. 01:30 - 06:00 4.50 11 A EVALPR LOG WITH SCHLUMBERGER. FIRST RUN USIT. HAVING PROBLEMS WITH USIT TOOL AT REPORT TIME. 5/29/2001 06:00 - 09:00 3.00 11 !A EVALPR RIH WITH SCHLUMBERGER WlRELINE (RST) RUN #1, ATTEMPT TO LOG, POH DUE TO TOOL FAILURE 09:00 - 13:00 4.00 11 ~A EVALPR RIH & LOG WITH RUN #2 (USIT, CBT) 13:00 - 16:30 3.50 11 A EVALPR CHANGE OUT TOOLS & RIH WITH (CHFR), RUN #3 16:30 - 06:00 13.50 11 A EVALPR LOG WITH CHFR TOOL ON SCHLUMBERGER WlRELINE, PC)H, PREP TO RIG DOWN S.O.S. EQUIP. 5/30/2001 06:00 - 08:00 2.00 11 A EVALPR LOG WITH CHFR TOOL (RUN #3), ON SCHLUMBERGER WlRELINE, POH & RIG DOWN S.O.S. EQUIPMENT 08:00 - 10:30 2.50 26 EVALPR RUN 11 STANDS OF 2 7/8" DRILL PIPE FROM DERRICK & STRAP, DRIFT & P/U 9 JOINTS OF 2 7/8" D.P., WITH PORTED MULE SHOE JOINT Printed: 7/23/2001 9:43:10AM FOREST OIL CORP. Page 2 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date From - To Hours Code (~o~ Phase .................................................................................................... L .............................. l .......... ~...e... ...................................... Description of Operations 5/30/2001 10:30 - 18:30 8.00126 EVALPR STRAP, DRIFT & PICK UP 3 1/2" 9.2 LBS/FT, L-80 TUBING, RIH 18:30- 19:30 I 1.00; 25 EVALPR OFF LOAD P.T.S. EQUIP FROM SERVICE BOAT 19:30 - 06:00 10.501 26 EVALPR CONTINUE STRAP, DRIFTING & PICKING UP 3 1/2" TUBING; RIH WITH 2 718" PORTED MULE SHOE 5/31/2001 06:00 - 11:00 5.00 26 EVALPR STRAP, DRIFT & PICK UP 3 1/2" TBG. L-80, 9.2 LBS/FT. 11:00 - 06:00 19.00 05 A EVALPR TAGGED UP PBTD @ 15270', RIG UP CIRC HEAD & REVERSE ClRC THRU PORTED MULE SHOE @ 15268', FILTER 5 % KCL COMPLETION FLUID THRU 10 MICRON FILTER SYSTEM, (P.T.S. CREW HAS BEGAN SETTING & RIGGING UP D.S.T. EQUIPMENT) 6/1/2001 06:00 - 09:00 3.00 05 A EVALPR REV. CIRC THRU PORTED MULE SHOE, FILTER 5% KCL COMPLETION FLUID THRU 10 MIC FILTERS 09:00 - 17:00 8.00 06 E EVALPR POH WITH 3 1/2" TBG (CHANGE OUT TEFLON SEAL RINGS IN COUPLINGS) & 2 7/8" DRILL PIPE, LAY DOWN PORTED MULE SHOE 17:00 - 23:00 6.00 15 A EVALPR TEST BOPE: (AOGCC WAIVED WlTTNESSlNG TEST) HYDRIL BAG FROM 250 PSI TO 3500 PSI, RAMS, IBOP VALVES, CHOKE MANIFOLD, MUD CROSS LINES, FLOOR VALVES FROM 250 PSI TO 4000 PSI, PERFORM KOOMEY TIME TEST, INSTALL WEAR BUSHING 23:00 - 00:30 1.50 25 EVALPR SET DST TOOLS & HANDLING TOOLS ON RIG FLOOR, PREP RIG FLOOR TO PICK UP 3 3/8" GUNS 00:30 - 01:00 0.50 25 EVALPR HELD PRE JOB SAFETY MEETING WITH HALLIBURTON REPS ON PROPER PERF GUN HANDLING & DST ASSY. MAKE UP 01:00 - 06:00 5.00 16 D EVALPR PICK UP 3 3/8", 6 SHOTS PER FOOT, 60 DEC PHASE PERFORATION GUNS & DST ASSY. AS PER PROC. 6/2/2001 06:00 - 06:30 0.50 16 D EVALPR STRAP, DRIFT & PICK UP 2 7/8"TBG AS PART OF THE DST ASSY. 06:30 - 08:30 2.00 16 D EVALPR STRAP, DRIFT & MAKE UP 7 5/8" CHAMP PACKER & REMAINING MISC. DST ASSY. TOOLS, STEEL LINE MEASUREMENT FROM R.A. SOURCE (SUB) TO TOP SHOT - 574.65' 08:30 ~ 19:00 10.50 06 K EVALPR RIH WITH 3 1/2" TBG. 19:00 - 20:00 1.00 25 EVALPR CHANGE OUT TOP DRIVE BALES, MAKE UP 16' OF 3 1/2" TBG. PUP JOINTS, (110K DOWN WEIGHT & 175K UP WEIGHT IN 5 1/2" LINER) 20:00 - 21:00 1.00 11 F EVALPR RIG UP SCHLUMBERGER WlRELINE EQUIPMENT, HANG SHEAVE !AT DERRICK BOARD, MAKE UP COLLAR LOCATOR & GR TOOLS 21:00 - 00:00 3.00 11 F EVALPR 'RIH WITH COLLAR LOCATOR & GR TOOLS, CORRALATE R.A. SUB & PERF. GUNS TOP SHOT TO PROPER DEPTH 00:00 - 02:00 2.00 11 F EVALPR POH WITH S.O.S. WlRELINE GAMMA ATC TOOLS 02:00 - 03:00 1.00 16 C EVALPR SPACE OUT DST STRING WITH PUP JOINTS, 3 1/2" TBG COUPLING PARTED AFTER MAKE UP OF PUP JOINT, DROPPED DST ASSY. DOWN HOLE 03:00 - 04:00 1.00 11 F EVALPR RIG DOWN SCHLUMBERGER EQUIPMENT & MAKE READY FOR BACK LOAD ONTO SERVICE BOAT 04:00 - 06:00 2.00 19 E !EVALPR LAY DOWN LONG TOP DRIVE BALES, PICK UP SHORT LINK TILT BALES, MAKE READY FOR FISHING DST STRING, MONITOR WELL FOR LOSS OR GAINS 6/3/2001 06:00 - 07:00 1.00 19 E EVALPR WAIT ON BAKER TOOL FISHING REP. & TOOLS, CLEAN & ORGANIZE RIG FLOOR, SERVICE RIG & TOP DRIVE 07:00 - 09:00 2.00 19 E EVALPR MAKE UP OVERSHOT ON TO 2 - STANDS OF 5" DRILL PIPE, TAG TOP OF FISH @ 145', ENGAGE FISH & POH 09:00 - 20:00 11.00 06 E EVALPR STAND BACK 5" DRILL PIPE, LAY DOWN FISH OVERSHOT TOOL, POH WITH 3 1/2" TBG STRING & DST ASSY. STAND BACK 3 1/2" IN DERRICK Printed: 712312001 9:43:10 AM FOREST OIL CORP. page 3 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date From- To Hours l Code ICo~eSub Phase/ Description of Operations 6/3/2001 20:00 - 22:30 2.50 19 !E EVALPR MONITOR WELL LAY DOWN DST TOOLS. STATUS OF FISHED I [ ~ , DST TOOLS: O~NI VALVE HAD SHIFTED BUT BALL VALVE OPEN [ I& LPRN CLOSED FROM IMPACT, JUNK LEFT IN HOLE: 1/2 CHAMP PKR ELEMENT(RUBBER), 3- DRAG BLOCKS W/12- DRAG SPRINGS, 6- SET SCREWS, 4 - LUGS FROM PKR, RD SAFETY JOINT MANDREL HAS BEEN BENT 22:30 - 23:00 0.50 19 E EVALPR HELD PRE JOB SAFETY MTG. ON PROPER LIVE GUN HANDLING & PROCEDURES 23:00 - 03:30 4.50 19 E EVALPR STAND BACK 2 7/8" TBG, LAY DOWN 3 3/8" GUNS, APPEARS THAT DST #1 PERF ZONE DID NOT FIRE (PROPOSED PERF DEPTHS OF 14612' TO 14420'), PROPOSED BOTTOM DST #2 PERF ZONE FROM 15156' TO 14682' = (474')', DID FIRE. ACTUAL TOP SHOT OF BO-I-I'OM ZONE = 14760', ACTUAL BOTTOM SHOT OF BOTTOM ZONE = 15234' = 78' DEEPER THAN PROPOSED PERF SCHEDULE. GUN #1 (BOTTOM ZONE ) HAD THE TOP 16' SHOOT OUT OF SCALLOP, THE REMAINING 5' SHOT IN SCALLOP, GUN #18 HAD THE TOP 13' SHOOT OUT OF SCALLOP, THE REMAINING 8' SHOT IN SCALLOP 03:30 - 04:00 0.50 25 EVALPR CLEAN & ORGANIZE RIG FLOOR & CLEAR RIG FLOOR OF EXCESS TOOLS 04:00 - 05:30 1.50 09 EVALPR CUT & SLIP 107' OF DRILLING LINE 05:30 - 06:00 0.50 06 B EVALPR RIH WITH 2 7/8" & 3 1/2" TBG TO BE LAYED DOWN TO BE INSPECTED AT TUBESCOPE, (NOTE: 3 1/2" TBG 8' PUP & JOINT THAT PARTED ARE BEING STORED AT TUBESCOPE) 6/4/2001 06:00 - 06:30 0.50 06 B EVALPR RIH WITH FISHED DST 2 7/8" TBG, POH LAYING DOWN SAME 06:30 - 13:00 6.50 06 B EVALPR RIH WITH FISHED 3 1/2" TBG STRING, MONITOR DISPLACEMENT (WELL STABLE) 13:00 - 13:30 0.50 07 EVALPR SERVICE RIG, TOP DRIVE, TRAVEL BLOCKS & CROWN SHEAVES 13:30 - 06:00 16.50 06 B EVALPR LAY DOWN FISHED 3 1/2" TBG STRING TO BE LOADED OUT ON BOAT & INSPECTED AT TUBESCOPE 6/5/2001 06:00 - 14:00 8.00 25 EVALPR LOAD OUT WORK BOAT. RECEIVE LOGGIING TOOLS. 14:00 - 17:00 3.00 11 F EVALPR RIG UP SCHLUMBERGER. 17:00 - 20:00 3.00 11 F EVALPR RUN 8.5" GAUGE RING AND JUNK BASKET TO TOP OF 7 5/8 LINER. DID NOT RECOVER AND JUNK. 20:00 - 23:00 3.00 11 F EVALPR RUN 5.97" GAUGE RING AND JUNK BASKET TO TOP OF 5 1/2' LINER. DID NOT RECOVER ANY JUNK. 23:00 - 02:30 3.50 11 F EVALPR RUN 4.4" GAUGE RING INTO TOP OF 5 1/2" LINER. SOME PROBLEMS ENTERING LINER TOP AND TIGHT AREAS DOWN IN LINER THROUGH PERFORATIONS. RUN TO BOTTOM. RECOVERED SOME SMALL PIECES OF DRAG BLOCK SPRINGS. RAN WITH COLLAR LOCATOR AND GAMMA RAY LOCATING AREAS PERFORATED PREVIOUSLY. 02:30- 06:00 3.50 11 F EVALPR CHANGE TOOLS TO PERFORATION GUNS. 6/6/2001 06:00 - 06:00 24.00 11 F EVAL 1 PERFORATE WITH SCHLUMBERGER. FIRST RUN SHOT 20' OVER 15152' TO 15136'. SECOND RUN SHOT 20' OVER 15020' TO 15002'. THIRD RUN SHOT 40' OVER 14980' TO 14948'. FORTH RUN SHOT 40' OVER 14788' TO 14748'. FIFTH RUN SHOT 40' OVER 14748' TO 14708'. SIXTH RUN SHOT 30' OVER 14708' TO 14682'. ] PULLING OUT OF THE HOLE AT REPORT TIME. ALL SHOTS FIRED. 6/7/2001 06:00 - 08:00 2.00 11 F EVALPR LAY DOWN SCHLUMBERGER PERFORATION GUNS. Printed: 7/23/2001 9:43:10AM .., FOREST OIL CORP. Page 4 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date i' From - To Hoursl Code CodeSUb Phase Description of Operations 6/7/2001 08:00 - 10:00 2 001111 F [ EVALPR RUN 4.4" GAUGE RING AND JUNK BASKET TO BOTTOM ~' I I~ INSPECT JUNK BASKET - NO DEBRIS INSIDE ' i10:00-15:30 5.50 11 F EVALPR I SET BAKER CEMENT RETAINER AT15218' WIRE LINE MEASURE. 115:30 - 16:30 1.00 11 F EVALPR RIG DOWN SCHLUMBERGER. 116:30- 17:30 1.00 16 C EVALPR DRESS HALLIBURTON'S DRILL STEM TEST HEAD. !17:30 - 20:30 3.00 16 B EVALPR PICK UP DST TOOLS. 20:30 - 06:00 9.50 06 E EVALPR STRAP, RABBIT AND PICK UP 3 1/2" DRILL PIPE. 6/8/2001 06:00 - 11:00 5.00 06 E EVALPR RIH WITH DST. 11:00- 13:00 2.00 16 D EVALPR RIG UPTEST HEADAND LINES. 13:00 - 16:00 3.00 16 D EVALPR UNLOAD WORK BOAT WITH TEST EQUIPMENT. 16:00 - 00:00 8.00 16 D EVALPR RIG UP SEPARATOR, LINE HEATER, SCRUBBER ETC. 00:00- 00:30 0.50 16 D EVALPR SET PACKER AT 14048'. 00:30 06:00 5.50 16 D EVALPR PRESSURE TESTING LINES ANDVALVES. 6/9/2001 06:00- 07:00 1.00 16 C EVALPR FINISH TESTING SURFACE EQUIPMENT. 07:00- 08:00 1.00 16 C EVALPR SAFETY MEETING. 08:00 - 09:00 1.00 16 C EVALPR TEST N2 LINES TO 2500 PSI. AND FLARE LINE TO 100 PSI. 09:00 - 11:00 2.00 16 C EVALPR PUMP 1735 PSI N2 INTO DRILL PIPE. 11:00 - 11:30 0.50 16 C EVALPR CLEAR N2 LINES. OPEN LPRN TESTER VALVE. 11:30 - 12:00 0.50 16 C EVALPR WELL OPEN AT LPRN. CLOSED ON SURFACE. 12:00 - 06:00 18.00 16 C EVALPR WELL ON DST OPEN TO TEST. 6/10/2001 06:00 - 07:00 1.00 16 C EVALPR WELL ON DST OPEN TO SURFACE. 07:00- 03:00 20.00 16 C EVALPR WELL SHUT IN. 03:00 - 06:00 3.00 16 C EVALPR OPENED WELL TO SECOND FLOW PERIOD. 6/11/2001 06:00 - 11:00 5.00 16 C EVALPR OPEN LPRN TEST VALVE & FLOW WELL, RIG UP & RIH W/OIL PHASE SAMPLE THRU LUBRICATOR, CATCH 3 SAMPLES 11:00 - 14:30 3.50 16 C EVALPR SHUT IN LPRN TEST VALVE, POH WITH OIL PHASE TOOL ON S.O.S. WIRELINE, RIG DOWN S.O.S., CLEAR RIG FLOOR OF WIRELINE EQUIP. 14:30 - 15:00 0.50 16 C EVALPR CYCLE LPRN VALVE 7 TIMES TO REVERSE ClRC POSITION 15:00 - 16:30 1.50 05 B EVALPR RIG UP TO & REVERSE ClRC, TAKING RETURNS TO 500 BBL UPRIGHT TANK, CHECK RETURNS FOR 8.6 PPG 5% KCL BRINE H20 16:30 ~ 18:00 1.50 05 B EVALPR RIG UP TO ClRC CONVENTIONALLY, FLUSH OUT PTS LINES / MANIFOLD & VAC OUT WITH SWACO DSR, 18:00 - 21:00 3.00 05 B EVALPR PULL 7 5/8" CHAMP PKR FREE & ClRC CONVENTIONALLY THRU RIG CHOKE 21:00 - 23:00 2.00 05 B EVALPR CHECK FLOW, OPEN HYDRIL BAG, CIRC OUT GAS CUT BRINE 23:00 - 01:00 2.00 16 C EVALPR MONITOR WELL, LAY DOWN TEST HEAD & PTS MANIFOLD, CHANGE OUT BALES 01:00 - 04:00 3.00 06 E EVALPR POH WITH DST ASSY.#1, MONITOR WELL AT 8700' (ABOVE 7 5/8" LINER TOP), WELL STATIC 04:00 - 06:00 2.00 06 E EVALPR POH WITH DST ASSY. #1 6/12/2001 06:00 - 08:00 2.00 06 E EVALPR POH WITH DST ASSY. #1, WELL TAKING PROPER DISPLACEMENT 08:00 - 10:00 2.00 16 C EVALPR LAY DOWN TEST TOOLS, COLLECT & DOWN LOAD GAUGES 10:00 - 17:30 7.50 15 A EVALPR TEST BOPE FROM 250 PSI TO 4000 PSI, HYDRIL BAG FROM 250 PSI TO 3500 PSI, PERFORM KOOMEY TIME TEST, TEST COMBUSTIBLE ALARMS, REINSTALL WEAR RING 17:30 - 21:30 4.00 11 F EVALPR RIG UP SCHLUMBERGER EQUIPMENT, RIH WITH 4.5" GAUGE RING, JUNK BASKET & GR TO 14760', (GOOD TRIP), POH 21:30 - 22:30 1.00 11 F EVALPR RIG UP TO RIH WITH HALLIBURTON 5 1/2" "FAS DRILL PACKER" 22:30 - 01:00 2.50 11 F EVALPR RIH WITH "FAS DRILL PKR" TO14670', CORRELATE TO DEPTH i WITH GR TOOL, SET TOOL @ 14670', TAG UP ON PKR @ 14681' = i I I Printed: 7/23/2001 9:43:10AM FOREST OIL CORP. Page 5 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date From-TolHours Code /cSoUdbe Phase/ DescriptionofOperations 6/12/2001 i 22:30-01:00 2.50 11 F EVALPR 11' DROP (TOP SHOT OF LOWER PERF ZONE @ 14682') 01:00- 02:30 1.501 11 F EVALPR POH WITH SCHLUMBERGER SETTING TOOL (CPST) 102:30- 03:00 0.50 11 :F EVALPR OBSERVED 3.42', 3 3/8" O.D. OF CPST HAS BEEN LEFT IN HOLE I IWITH 1.33', 4.15 O.D. OF BAKER 20 WIRELIKE ADAPTER KIT TOTAL TOOLS ON TOP OF"" FAS DRILL" PKR = 4.75','~FAS DRILL' I PKR LENGTH = 2.42' 03:00 - 04:00 ' 1.00 25 EVALPR PRESSURE TEST CASING / LINERS @ 2000 PSI FOR 30 MINS. TO VERIFY "FAS DRILL" PKR HAS SET PROPERLY, (GOOD TEST) 04:00 - 05:00 1.00 11 F EVALPR RIG DOWN SCHLUMBERGER WlRELINE EQUIPMENT ~05:00 - 06:00 1.00 16 C EVALPR PREP TO PICK UP 3 3~8", 6 SPF, 60 DEG PHASE PERF GUNS, HOLD PRE JOB SAFETY MEETING, WHILE OFF LOADING BOAT 6/13/2001 06:00 - 12:00 6.00 06 E EVALPR P/U 3 3~8", 6 SPF, 60 DEG PHASE HALLIBURTON PERF GUNS, OFF LOAD BOAT 12:00 - 14:30 2.50 06 E EVALPR P/U 2 7/8" TBG & HALLIBURTON TEST TOOLS 14:30 - 20:00 5.50 06 E EVALPR RIH WITH DST ASSY #2 20:00 - 21:00 1.00 06 E EVALPR ATTEMPT TO WORK 7 5/8" CHAMP PKR, INTO TOP OF 7 5/8" LINER 21:00 - 22:00 1.00 06 E EVALPR POH TO PLACE END OF GUNS AT TOP OF 7 5/8" LINER TOP, RIH AND ATTEMPT TO PASS CHAMP PKR INTO TOP OF LINER, NO SUCCESS 22:00 - 02:00 4.00 06 E EVALPR POH WITH DST ASSY #2 TO CHECK CHAMP PACKER ELEMENT OR DISCREPANCIES 02:00 - 03:00 1.00 16 C EVALPR OBSERVED MIDDLE CHAMP PKR RUBBER WAS EGGED SHAPED & STRETCHED, LAY DOWN PKR, DISASSEMBLE PKR & INSPECT RUBBERS 03:00 - 04:30 1.50 25 EVALPR TRANSPORTING HALLIBURTON CHAMP PKR RUBBERS TO OSK HELIPORT FOR DELIVERY TO OSPREY PLATFORM 04:30 - 05:30 1.00 16 C EVALPR INSTALL RUBBER ELEMENTS ONTO CHAMP PKR, MAKE UP ON DST ASSY #2, CHANGE OUT LPRN SHEAR PINS, FILL TOOL ASSY + 1 STAND OF 3 1/2" DRILL PIPE WITH WATER FOR DROP BAR CUSHION 05:30 - 06:00 0.50 06 E EVALPR RIH WITH DST ASSY #2 6/14/2001 06:00 - 12:00 6.00 06 E EVALPR M/U REDRESSED HALLIBURTON CHAMP PKR, RIH WITH DST#2 12:00 - 12:30 0.50 07 EVALPR SERVICE RIG & TOP DRIVE 12:30 - 15:30 3.00 06 E EVALPR RIH TO 14632' (END OF PERF GUN ASSY) 15:30 - 18:00 2.50 11 F EVALPR RIG UP SCHLUMBERGER EQUIP, RIH WITH ATC & COLLAR LOCATOR TOOLS, CORRELATE P.A. MARKER & DST #2 PERF TOP SHOT TO PROPER DEPTH 18:00 - 18:30 0.50 11 F EVALPR SPACE OUT DST TO PLACE TOP SHOT ON DEPTH 18:30 - 20:30 2.00 11 F EVALPR RIH WITH SCHLUMBERGER ATC & COLLAR LOCATOR & VERIFY R.A MARKER IS ON PROPER DEPTH (OK), POH & RIG DOWN 20:30 - 22:00 1.50 16 C EVALPR CHANGE OUT BALES ON TOP DRIVE, MAKE UP TEST HEAD, (LOAD DROP BAR), SET CHAMP PKR WITH 25K DOWN WEIGHT @ 14022' 22:00 - 00:00 2.00 16 C EVALPR RIG UP PTS CHOKE MANIFOLD, FLOW LINES, EMERGENCY SHUT IN VALVE, DEAD WEIGHT SCALES 00:00 - 01:30 1.50 16 C EVALPR TEST PTS CHOKE MANIFOLD, EMERGENCY SHUT IN VALVE & TEST HEAD TO 4000 PSI, FLOW LINE TO SEPARATOR TO 1000 PSI 01:30 - 02:30 1.00 16 C EVALPR RIG UP N2 LINE TO TEST HEAD, HELD PRE JOB SAFETY MTG. 02:30 - 04:30 2.00 16 C EVALPR TEST N2 LINE TO 4000 PSI, LINE UP TO & CHARGE DRILL STRING WITH N2 TO 1900 PSI, (LPRN VALVE CLOSED) WHILE MONITORING ANNULUS Printed: 7/23/2001 9:43,:10AM FOREST OIL CORP. Page 6 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date ' From - To Hours Code1 cSoUdbe ' Phase/ Description of Operations 6/14/2001 04:30 - 05:00 0.50 16 i C EVALPR CLOSE HYDRIL BAG, PRESSURE ANNULUS TO 2000 PSI, HOLD I]~ . FOR 30 MINS (ANNULUS & DRILL PIPE PRESSURES STABLE) !05:00 - 05:30 0.50 16 C I EVALPR DROP DETONATOR BAR DOWN DRILL STRING, OBSERVE I PRESSURE INCREASES ON DEAD WEIGHT SCALE, @ START = 1893 PSI, 30 MINS LATER = 2371 PSI BEFORE OPENING UP 16 / 64"CHOKE 05:30 - 06:00 0.50l 16 C EVALPR FLOW THRU 16 / 64" CHOKE TO SEPARATOR, MONITOR PRESSURE & VOLUME READINGS 6/15/2001 06:00 - 19:00 13.00~ 16 C EVALPR DST#2 PERF ZONE DEPTHS 14420' TO 14612' (184' OF SHOTS, 6 SPF, 8' OF BLANK). FLOW PERIOD #1 THRU 16 / 64th CHOKE FROM 0530 HRS TO 1200 HRS, OPEN UP CHOKE TO 2" BY PASS FROM 1200 HRS TO 1900 HRS 19:00 - 06:00 11.00 16 C EVALPR BLEED ANNULUS OFF TO CLOSE LPRN TESTER VALVE @ 13978' M.D., ALLOW DRILL STRING & SURFACE FLOW LINES & MANIFOLD TO BLEED OFF. RESTRAP FLOW TANKS "B" & "C" FOR i TOTAL FLOW VOLUMES, CHANGE OUT SCHLUMBERGER ~ WlRELINE DRUM FROM .46 E-LINE TO .23 LINE FOR "OIL PHASE" i C B.H. SAMPLES 6/16/2001 06:00 - 09:00 3.00 16 EVALPR SHUT IN / BUILD UP PERIOD #2 (SHUT IN @ LPRN TESTER VALVE), RESTRAP FLOW TANKS 09:00 - 10:30 1.50 16 = C EVALPR APPLY 2000 PSI TO ANNULUS TO OPEN LPRN TESTER VALVE i FOR MAJOR FLOW PERIOD #1, 0902 HRS - 155 PSI @ SURFACE, , 0905 HRS - OPEN BYPASS (2") F/CHOKE MANIFOLD TO FLOW TANKS, 0933 HRS - FLUID TO SURFACE 10:30 - 13:30 3.00 16 'C EVALPR RIH WITH OIL PHASE B.H. SAMPLE TOOL ON SCHLUMBERGER WlRELINE (LUBRICATOR TESTED TO 2500 PSI), TO 13892' = 40' ABOVE DST BALL VALVE TOOLS, TAKE 3 SAMPLES @ 15 MIN INTERVALS 13:30 - 15:30 2.00 16 C EVALPR BLEED OFF PRESSURE FROM ANNULUS TO CLOSE LPRN TESTER TOOL, (STRAP FLOW TANKS & BEGIN INJECTION OF PRODUCED FLUIDS), SHUT IN / BUILD UP PERIOD #3 15:30 - 17:30 2.00 16 C EVALPR POH WITH SCHLUMBERGER WlRELINE OIL PHASE TOOL, RIG DOWN SCHLUMBERGER EQUIP FROM RIG FLOOR 17:30-06:00 12.50 16 C EVALPR 1743 HRS - OPEN LPRN TESTER VALVE WlTH1800 PSI TO ANNULUS, MONITOR SURFACE PRESSURE BUILD UP, 1750 HRS ~ 20 PSI, 1801 HRS - OPEN BYPASS (2") F/CHOKE MANIFOLD TO FLOW TANK, 1825 HRS (43 MINS FROM OPENING LPRN TESTER : VALVE) OBSERVED FLUID @ SURFACE, MONITOR TIMES, PRESSURES, FLOW RATES & CUMULATIVE VOLUME 6/17/2001 06:00 - 06:00 24.00 16 i C EVALPR DST #2 MAJOR (#2) FLOW PERIOD, MONITOR TIMES, I PRESSURES, FLOW RATES & CUMULATIVE VOLUME, DST #2, ' FLOW PERIOD #2: OPEN LPRN @ 1743 HRS, FLUID TO SURFACE I @ 1825 HRS JUNE 15th, AS OF 0600 HRS (35.5 HRS) JUNE I 17th,TOTAL FLOW FROM WELL #1 & 2 ZONES - 1879.55 BBLS, AVERAGE OVER LAST 24 HRS = 728.97 BOPD, GRAVITY = 27.9, BS & W = 0, 100% OIL, 0% WATER 6/18/2001 06:00 - 10:30 4.50 16 C EVALPR DST #2 FLOW PERIOD, MONITOR TIMES, PRESSURES, FLOW I RATES & CUMULATIVE VOLUME. DST FLOW PERIOD #2: OPEN LPRN @ 1743 HRS, FLUID TO SURFACE @ 1825 HRS JUNE 15th, AS OF 1030 HRS (40 HRS) JUNE 17th,TOTAL FLOW FROM WELL #1 & 2 ZONES = 2013 BBLS, 728.97 BOPD AVERAGE OVER LAST 24 HRS, GRAVITY - 28.1, BS & W = 0, 100% OIL, 0% WATER Printed: 7/23/2001 9:43:10AM FOREST OIL CORP. Page 7 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Hours Code Phase Description of Operations t I ............................ [ .............................. _~,~.~.Date From- To 6/18/2001 ~10:30 - 11:30: 1.00 16 C EVALPR BLEED OFF ANNULUS PRESSURE TO CLOSE LPRN, CYCLE OMNI I TO LAST TEST POSITION ALLOW B.H. PRESSURE TO STABILIZE FOR 15 MINS, CONTINUE CYCLING TO REVERSE CIRC POSITION i11:30 - 13:00 1.50 05 B EVALPR REVERSE CIRC DRILL STRING VOLUME 13:00 - 14:30 1.50 16 C EVALPR RIG DOWN PTS EQUIPMENT, FLUSH PTS CHOKE MANIFOLD & FLOW LINES, RIG UP TO ClRC CONVENTIONALLY 14:30 - 19:00 4.50 05 B EVALPR UNSEAT CHAMP PKR W/280K PULL WT., CIRC THRU RIG CHOKE MANIFOLD WITH 100 PSI BACK PRES., MONITOR GAS UNITS, MAX = 1470 UNITS ,19:00 - 20:30 1.50 05 B EVALPR SHUT WELL IN, MONITOR WELL CASING & DRILL PIPE PRES, 0 I PSI, OPEN WELL OBSERVED PENCIL SIZE STREAM FROM WELL, MAKE UP 200 BBLS OF 8.7 PPG OF KCL BRINE COMPLETION FLUID ~20:30 - 00:30 4.00 05 B EVALPR RESET CHAMP PKR & CIRC OUT GAS THRU GAS BUSTER W/8.7 PPG BRINE, OBSERVED 1250 UNITS OF GAS, OPEN HYDRIL BAG 00:30 - 02:30 2.00 05 B EVALPR PUMP 1 DRILL PIPE VOLUME OF 8.7 PPG BRINE, UNSEAT CHAMP PKR, CLOSE HYDRIL BAG & BULL HEAD 15 BBL BELOW PKR, OPEN HYDRIL BAG NO FLOW 02:30 - 04:30 2.00 16 C EVALPR LAY DOWN TEST HEAD, CHANGE OUT TOP DRIVE BALES 04:30 - 06:00 1.50 09 EVALPR CUT & SLIP DRILL LINE, PREP TO POH WITH DST #2 ASSY. 6/19/2001 06:00- 12:00 6.00 06 E EVALPR POH WITH DST. 12:00- 12:30 0.50 07 EVALPR RIG SERVICE. 12:30 - 15:30 3.00 06 E EVALPR POH WITH DST. 15:30 - 19:30 4.00 06 E EVALPR LAY DOWN DST TOOLS. ALL SHOTS FIRED. 19:30 - 20:30 1.00 06 E EVALPR BREAK DOWN DST TEST HEAD. 20:30 - 04:30 8.00 15 A EVALPR TEST BOP. ANNULAR PREVENTER FAILED. 04:30 - 06:00 1.50 07 EVALPR CHANGE OUT HYDRILL PACKING ELEMENT. 6/20/2001 06:00 - 10:30 4.50 07 EVAL 1 CHANGE OUT HYDRILL PACKING ELEMENT. 10:30 - 11:00 0.50 15 A PRESSURE TEST ANNULAR TO 250 - 3500 PSI 11:00 - 12:00 1.00 15 A PULL TEST PLUG. SET WEAR RING. 12:00 - 12:30 0.50 07 RIG SERVICE. 12:30 - 14:00 1.50 08 E REPAIR RIG WEIGHT INDICATOR. 14:00 - 23:00 9.00 06 B PICK UP FISHING TOOLS, 3 5/8" OVERSHOT AND RIH. 23:00 - 00:00 1.00 19 B FISHING AT 14642' DRILL PIPE MEASUREMENT. 00:00 - 06:00 6.00 06 B POH WITH FISHING TOOLS. WELL STATIC. 6/21/2001 06:00 - 11:30 5.50 06 B POH WITH OVERSHOT. FOUND LARGE PIECE OF HYDRILL RUBBER IN BARREL. DID NOT RECOVER ANY FISH. 06:00 - 11:30 5.50 06 B POH WITH OVERSHOT. FOUND LARGE PIECE OF HYDRILL RUBBER IN BARREL. DID NOT RECOVER ANY FISH. 11:30 - 12:00 0.50 07 RIG SERVICE. 11:30 - 12:00 0.50 07 RIG SERVICE. 12:00 - 19:00 7.00 06 B EXTEND BARREL ON OVERSHOT. RIH. 12:00 - 19:00 7.00 06 B EXTEND BARREL ON OVERSHOT. RIH. 19:00 - 20:00 1.00 19 E , FISHING AT 14643'. WITH 3 5/8" OVERSHOT. 19:00 - 20:00 1.00 19 lB FISHING AT 14643' WITH 3 5/8" OVERSHOT. 20:00 - 05:00 9.00 06 B POH WET. 20:00 - 05:00 9.00 06 B POH WET. 05:00 - 06:00 1.00 19 B DRESS FISHIONG TOOLS. 05:00 - 06:00 1.00 27 NO RECOVERY WITH OVERSHOT. i DRESS FISHING TOOLS. Printed: 7/23/2001 9:43:10AM FOREST OIL CORP. Page 8 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date IFrom-TolHours Code CodeSUb..___P__~h_a_.s....e_... 6/22/2001 06:00 - 06:30 0.50 07 RIG SERVICE. 06:30 15:30 9.00 06 i B DRESS FISHING BASKET. RIH TO TOP OF 5 1/2" LINER. 15:30 17:00 1.50 09 CUTAND SLIP DRILLING LINE. 17:00 - 17:30 0.50 06 B RIH TO TOP OF FISH. 17:30 - 19:00 1.50 06 B FISHING AT 14643'. WORK BASKET OVER FISH. 19:00 - 03:00 8.00 06 B POH. DID NOT RECOVER ANY FISH OR RUBBER DEBIS. 03:00 - 06:00 3.00 06 B DRESS OVERSHOT WITH 3 1/2" SPIRAL GRAPPLE. RIH. 6/23/2001 06:00 - 11:00 5.00 06 B RIH WITH 3.5" OVERSHOT. 11:00 - 13:00 2.00 19 B FISHING AT 14643'. 13:00 - 18:30 5.50 06 B POH. WET. 18:30 - 19:00 0.50 08 B REPAIR TOP DRIVE. 19:00 - 19:30 0.50 07 RIG SERVICE. 19:30 - 00:00 4.50 06 B POH. WET. 00:00 - 01:00 1.00 19 B RECOVERED SCHLIMBERGER PACKER SETTING TOOL. FULL RECOVERY. BREAK DOWN FISHING TOOLS. 01:00 - 06:00 5.00 06 A MAKE UP MILL AND MUD MOTOR. RIH TO DRILL OUT HALLIBURTON FAST DRILL RETAINER. 6/24/2001 06:00 - 09:00 3.00 06 A RIH WITH MUD MTOR AND 4 3/4" BURN SHOE. 09:00 - 15:00 6.00 25 MILL OUT RETAINER AT 14647'. 15:00 - 15:30 0.50 06 RIH TO BOTTOM AT 15191'. PUSH JUNK AHEAD OF MILL. 15:30 - 04:00 12.50 06 POH. LAY DOWN 2 7/8" DRILL PIE AND 3 1/8" COLLARS. LAY DWN FISHING TOOLS. 04:00 - 05:00 1.00 25 PULL WEAR BUSHING. 05:00 - 06:00 1.00 CLEAR RIG FLOOR. PICK UP TOOLS. RIG TO RUN 3 1/2" TUBING. SAFETY MEETING. 6/25/2001 06:00 - 00:00 18.00 06 PICK UP COMPLETION STRING TO 13715'. STRAP, RABBIT AND RUN 3 1/2" EUE TUBING. 00:00 - 01:00 1.00 09 SAFETY VALVE DRILL. CUT DRILLING LINE. 01:00 - 06:00 5.00 25 CLEAN MUD PITS. 6/26/2001 06:00- 10:00 4.00 25 EVALPR CLEAN PITS & BUILD VOLUME 10:00 - 14:00 4.00 05 B EVALPR DISPLACE WELL WITH 8.7 PPG 5% KCL BRINE W/INHIBITOR, TAKE RETURNS TO SWACO DSR UNIT FOR INJECTION, 14:00 ~ 15:30 1.50 25 EVALPR MAKE UP OTIS X - NIPPLE WITH DUAL PX PLUG, RIH TO 13968', MAKE UP TBG HGR W/2 - WAY CHECK VALVE 15:30 - 19:00 3.50 05 EVALPR MAKE UP LANDING JOINTS, FLUSH BOPE & CLEAN LINES, PUMPS, DRAIN STACK & RISER 19:00 - 20:00 1.00 25 EVALPR LAND TBG HGR,PERFORM PRE TEST ON HGR SEALS (FAILED), PULL & CHANGE OUT O-RINGS ON HGR, LAND & RETEST TO 1000 I PSI (OK), LAY DOWN LANDING JOINTS, & CASING TOOLS, i ORGANIZE RIG FLOOR 20:00 - 05:00 9.00 14 B EVALPR NIPPLE DOWN BOPE, SET BACK ON STUMP & SECURE IN PLACE '05:00 - 06:00 1.00 14 B EVALPR PREP TO NIPPLE DOWN & REMOVE BOPE RISER FROM WELL HEAD ROOM TO PIPE RACK 6/27/2001 06:00 - 07:30 1.50 14 B EVALPR FINISH SECURING BOP ON STUB IN CELLAR, NIPPLE DOWN & REMOVE LOWER BOPE RISER FROM WELL HEAD ROOM TO PIPE RACK 07:30 - 09:30 2.00 25 EVALPR MAKE UP ADAPTER FLANGE & PRODUCTION TREE 09:30 - 11:30 2.00 25 EVALPR ATTEMPT TO TEST PRODUCTION TREE, 2 - WAY CHECK LEAKING, PULL & REINSTALL 2 - WAY CHECK, TEST PRODUCTION TREE BONET (HGR NECK SEALS & RING GASKET) Printed: 7/23/2001 9:43:10AM FOREST OIL CORP. Page 9 of 9 Operations Summary Report Legal Well Name: Redoubt Unit #2 Common Well Name: Redoubt Unit #2 Spud Date: Event Name: ORIG COMPLETION Start: 5/21/2001 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 429 Date From - ToI Hours Code/ (~oUdbe Phase ~ Description of Operations 6/27/2001 '09'30- 11.'30 I 2.00 25 EVALPR & PROD TREE BODY TO 5K-PSI WITH VETCO GRAY REP ' REMOVI~ 2-CHECK & INSTALL BPV 11:30 - 12:00 0.50 22 B EVALPR CLEAN UP WORK AREA IN WELL HEAD ROOM, RELEASE RIG FROM RU #2 : , Printed: 7/23/2001 9:43:10AM Page 1 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: TMD: 15,325.00 (ft) ... Redoubt Unit #2 Redoubt Unit #2 ORIG DRILLING NABORS ALASKA DRLG NABORS DRILLING TVD: 12,606.52 (ft) Spud Date: Start: 2/23/2001 End: Rig Release: Rig Number: 429 Calculation Method: Minimum Curvature " . :Section .. (.)...::... j_'... o.ooi o.oo 0.18 0.16 0.20 0.16 -0.131 -0.14 -0.15! -0.12 -0.16 srr # v.s. AZ~ (°) OH 125.06 I ~BUR .... .... Type - OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH I I ; 0.00 82.00 115.00 172.00 202.00 231.00: 261.001 291.00i 350.00! 413.00 5oo.ooi 530.00i 560.001 589.00, 589.001 651.00i 740.O01 801.00 890.00. 980.00! 1,070.00i 1,168.00i 1,259.00i 1,355.00 1,473.00i 1,572.26 1,666.65 1,762.27i 0.000! 0.2501 0.2501 0.100 O.lOOl 0.050 0.900 0.800 1.250 1.600 1.900 2.000 2.200 3.000 3.000 2.100 1.500i 2.100" 3,400 5.000~ 6.200 9.000! 11.5001 14.000 17.227~ 20.040' 22.010' 24.260 0.000j NYN 100.o0oj NYN 310.000 NYN 230.000 NYN 170.000 YNN 256.000 YNN 262.000 YNN 270.000 YNN 320.000 YNN 336.000 YNN 89.000 YNN 96.000 YNN 112.000 YNN 114.000 YNN 114.000 YNN 140.000 YNN 177.000 YNN 209.000 YNN 196.000 YNN 180.000 YNN 158.000i YNN 145.000 YNN 138.000 YNN 132.000 YNN 133.570 YNN 132.010 YNN 126.350 YNN 123.640 YNN 0.00' 82.00 115.00 172.00 202.00 231.00 261.00 291.00 349.99 412.97 499.95 529.93 559.91 588.88 588.88 650.82 739.78 800.75 889.64 979.40 1 068.98 I 166.12 I 255.66 1 349.29 I 462.92 1 556.97 1,645.08 1,733.01 0.00 -0.03 0.00 0.05 0.01 -0.02 -0.06 -0.09 0.40 1.73 2.87 2.82 2.55 2.03 2.03 0.50 -1.91 -3.68 -7.65 -14.14 -22.57 -33.75 -46.33 -61.21 -82.81 -104.33 -125.64 -147.15 -0.40 -0.85: -1.67~ -2.47' -1.521 -0.50, 0.55 1.76 1.76! 3.97; 5.08j 4.58j 3.o6! 2.33 4.15 10.53 20.68 35.72 58.99 82.28 108.55 139.34 -0.12 -0.30 -0.64 -1.60 -3.02 -2.89 -2.03~ -1.01 0.27~ 0.27; 2.96i 5.261 5.87] 6.90l 10.031 16.361 28.011 43.541 64.40i 95.86 127.28i 161.03i 198.58 i DLS (°/100ft) 0.00i 0.30~ 1,46 0.44 0.33 0.37 2.83 0.52 1.62 0.84 3.36 0.86 2.06 2,78 0.00 2.33 1.43 1.88 1.61 2.19 2.71 3.34 3.06 2.94 2.76 2.88 3.00 2.60 0.00 0.00 0.00 -0.26 0.00 -0.17 2.83 -0.33 0.76 0.56 0.34 0.33 0.67 2.76 0.00 -1.45 -0.67 0.98 1.46 1.78 1,33 2,86 2.75 2.60 2.73 2.83 2.09 2.35 GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS GSS MWD MWD MWD MWD Printed: 7123/2001 9:47:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: TMD: 15,325.00 (ft) ....... , OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH Redoubt Unit #2 Redoubt Unit #2 ORIG DRILLING NABORS ALASKA DRLG NABORS DRILLING TVD: 12,606.52 (ft) TMD i "Angle. ' · .......... :('_%: ................ L- ............ .._.(j..)....._2 ..... 1,858.79; 1,954.87i 2,049.32 ~: 2,146.80! 2,240.54i 2,334.04i 2,430.43' 2,523.87 2,622.09 2,717.95 2,815.41 2,910.99 3,002.84 3,099.00 3,196.00 3,290.39 3,384.41 3,481.60 3,576.75 3,671 .O9 3,767.05 3,864.78 3,959.00 4,058.16 4,151.10 4,245.80 4,342.30 4,436.33 26.740 29.650 32.970 35.430 34.840 34.85O 36.280 37.880 36.070 37.030 38.400 38.940 38.070 37.310 35.420 35.450 36.690 38.100 36.2501 37.0101 38.290 38.960i 39.500i 39.500~ 39.79OI 39.700; 39.370 36.190 124.910! 122.260i 120.0301 119.6701 120.380i 122.900i 124.360i 124.2201 124.0601 124.4801 124.360i 124.2201 124.1601 123.7601 123.350 124.080 124.800 125.000 125.870 125.260 124.280 124.400 124.930 125.040 125.590 125.110 125.170 124.700 Spud Date: Start: 2/23/2001 End: Rig Release: Rig Number: 429 Calculation Method: Minimum Curvature YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN 1,820.12 1,904.79 1,985.48 2,066.10 2,142.76 2,219.50 2,297.91 2,372.45i 2,450.91~ 2,527.921 2,605.021 2,679.64! 2,751.521 2,827.611 2,905.72! 2,982.63 3,058.621 3,135.83~ 3,211.65~ 3,287.35i 3,363.331 3,439.68! 3,512.66~ 3,589.18~ 3,660.74 3,733.561 3,807.981 3,882.29i -170.56 -195.62 -220.96 -248.23 -275.22 -303.24 -334.30 -366.03 -399.19 -431.33 -465.03 -498.68 -530.81 -563.66 -595.45 -625.82 -657.13~ -690.90~ -724.23 -756.961 -790.38! -824.80~ -858.69. -894.85] -929.131 -964.17! -999.52! -1,032.51 173.66 240.13 211.49 285.49 253.51 334.44 301.03 389.00 347.74 442.74 393.22 496.06 439.89 552.10 486.43 608.43 535.32 667.50 582.50 724.58 631.68 784.19 681.02 843.91 728.32 901.08 777.08 959.86 825.01 1,017.36 870.53 1,072.06 916.18 1,127.42 964.58 1,186.44 1,011.43 1,243.93 1,057.22 1,300.21 1,105.37 1,358.82 1,155.74 1,419.82 1,204.75~ 1,479.41 1,256.43i 1,542.48 1,304.81 1,601.78 1,354.20i 1,662.33 1,404.43! 1,723.76 1,451.64 1,781.35 DLS (o/1o~) Page 2 of 7 S/T # OH v.s. Az~ (o) 125.06 j ._ BUR ...... Type (°/100ft) ..................... 2 63 i 3.30i 3.72 2.53 0.771 1.54 1.73 1.71 1.85 1.03 1.41 0.57 0.95 0.83 1.96 0.45 1.39 1.46 2.02 0.89 1.47 0.69 0.67 o.o7J 0.49j 0.341 0.34 3.40 2.57 3.03 3.52 2.52 -0.63 0.01 1.48 1.71 -1.84 1.00 1.41 0.56 -0.951 -0.79 -1.95 0.03 1.32 1.45 -1.94i o.811 1.33] 0.69i 0.57! 0.001 0.31~ -0.10i -0.34~ -3.38 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD "~ -- MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Printed: 7123/2001 9:47:42AM Legal Well Name: Redoubt Unit #2 Spud Date: Common Well Name: Redoubt Unit #2 Start: 2/23/2001 Event Name: ORIG DRILLING End: Contractor Name: NABORS ALASKA DRLG Rig Release: Rig Name: NABORS DRILLING Rig Number: 429 TMD: 15,325.00 (ft TVD: 12,606.52 (ft) Calculation Method: Minimum Curvature S/T~'"' TMD ---~i...:..:n." ".:..' i..'. '.- .... .............. '"'."::". .'. ';~,' · " ' .... · . A .g!e..' .' .. · Azimuth......... :CTM.'..t TVD. .' N/-S' E/~W ...... :,:: ·. : ;. :;:~:;:: f. ,,, "" .:.(ft): ".- "."(.).'.":' . i: .': · ('":).""..'.I'. · '~.' (ft)" (ft). (ft). OH OH OH OH 4,532.58 4,629.77 4,726.97 4,819.94 4,917.53 5,012.48 5,108.53 5,204.28 5,298.62 5,393.29 5,490.01 5,586.40 5,681.31 5,774.851 5,871.501 5,966.801 6,035.71 6,131.90 6,228.45 i 6,324.24 6,419.69 ! 6,513.74 i 6,611.74i 6,707.221 6,802.23'· 6,896.12 6,992.99; 7,087.93~ OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH Oh OH OH OH Oh OH OH OH OH 39.2201 38.720j 38.540i 38.250! 37.8501 37.640i 37.640i 37.3601 37.490~ 37.530 37.230 37.160 37.030 37.440 37.670 37.600 37.880 37.970 37.910 37.340 37.160 36.890 36.390 36.230 35.930 35.640 35.970 36.200: 125.040i YNN , 3,958.431 125.090! 125.060 125.220 124.590 124.740 124.590 124.830 124.840 124.320 124.680 125.040 125.060 124.640 125.020 124.880 124.880 124.650 124.640 125.120 125.420 125.550{ 125.58oi 125.5ooi 125.690 126.180i 125.550i 125.600i YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN 4,034.001 4,109.93j 4,182.791 4,259.64 4,334.72 4,410.78 4,486.75i 4,561.67[ 4,636.761 4,713.62i 4,790.401 4,866.101 4,940.58 5,017.20 5,092.67 5,147.16 5,223.04 5,299.18 5,375.05 5,451.03 5,526.12 5,604.75 5,681.69 5,758.48 5,834.64 5,913.21 5,989.93 DLS (°/100fi) -1,066.17! -1,101.28. -1,136.15, -1,169.39 -1,203.811 -1,236.87i -1,270.23i -1,303.42' -1,336.171 -1,368.881 -1,402.141 -1,435.45i -1,468.32 -1,500.66i -1,534.31! -1,567.651 -1,591.77 -1,625.481 -1,659.23 -1,692.67 -1,726.03 -1,758.90 -1,792.92 -1,825.78 -1,858.35 -1,890.57 -1,923.77 -1,956.30 1,499.93! 1,549.96 1,599.62 1,646.84 1,696.17 1,743.97 1,792.22i 1,840.13i 1,887.19. 1,934.651 1,983.05i 2,030.861 2,077.72 2,124.17' 2,172.53. 2,220.221 2,254.831 2,303.391 2,352.23i 2,400.20. 2 447.37! 2 493.491 2 541.061 2 587.07i 2 632.571 2 677.02 2 722.95 2,768.43 1,840.21 1,901.34 1,962.02 2,019.76 2,079.91 2,138.03 2,196.68 2,254.97 2,312.30 2,369.95 2,428.66 2,486.93 2,544.18 2,600.77 2,659.68 2,717.88! 2,760.06i 2,819.18 2,878.54 2,937.01 2,994.79 3,051.42 3,109.90 3,166.44~ 3,222.39! 3,277.291 3,333.95. 3,389.87! Page 3 of 7 S/T# OH v.s. AZ~ (o) 125.06 BUR (°/100ft) 3.16 0.52 0.19 0.33 0.57 0.24 0.10 0.33 0.14 0.34 0.38 0.24 0.14 0.52 0.34 0.12 0.41 0.17 0.06 0.67 0.27 0.30 0.511 0.17 0.34; 0.43~ 0.51i 0.241 3.15 -0.51 -0.19 -0.31 -0.41 -0.22 0.00 -0.291 0.14 0.04 -0.31 -0.07 -0.14 0.44 0.24 -0.07 0.41 0.09 -0.06 -0.60 -0.19 -0.29 -0.51 -0.17 -0.32 -0.31 0.34 0.24 Type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Printed: 7/23/2001 9:47:42 AM Page 4 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: TMD: 15,325.00 (ft) · '""" /~n.g.!e. ::'.". i · I. ' '¢) '..I ...... :~ ....... ::::~ :::: ~ .................... :.: ....................... OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH 7,186.52 i 7,280.12! 7,376.99! 7,474.40 i 7,566.09! 7,662.921 7,757.79~ 7,852.13i 7,950.49 ~ 8,002.40 :~ 8,044.35 8,085.82 8,136.76 8,187.25 8,234.68 8,280.05 8,328.70 8,412.50 8,457.43 8,523.11 8,564.71 8,617.46 8,666.82 8,713.32 8,808.94 8,903.72 8,957.30! 9,081.951 Redoubt Unit #2 Redoubt Unit #2 ORIG DRILLING NABORS ALASKA DRLG NABORS DRILLING TVD: 12,606.52 (ft) "I -" · · · '(ft)' ¢) .=: ............. . 36.440i 35.820[ 35.6401 36.610 36.590 36.280 35.990 35.700 35.440 36.680 37.300 37.340 37.640 37.440 37.380 37.380 36.6201 36.130' 35.820 35.470 36.270 36.940. 37.340 37.170 36.840 35.840 35.380 37.120 124.8701 YNN 125.9601 YNN 125.810i YNN 125.320' YNN 125.400 YNN 125.650 YNN 125.640 YNN 125.330' YNN 124.890' YNN 124.720 YNN 124.080, YNN 123.900 YNN ~ 123.220i YNN ; 124.640' YNN i 124.240 YNN 123.620 YNN 124.430 YNN 123.080 NYN 123.290! NYN 123.720 NYN 123.630 NYN 123.630 NYN 123.590 NYN 123.660 NYN 123.590 NYN 123.930 NYN 123.090 NYN 122.930' YNN 6,069.37 6,144.97 6,223.60 6,302.28 6,375.89 6,453.80 6,530.42 6,606.89 6,686.90 6,728.86 6,762.37 6,795.35 6,835.77 6,875.80 6,913.48 6,949.53i 6,988.38i 7,055.85~ 7,092.211 7,145.59! 7,179.301 7,221.64~ 7,260.99j 7,298.00 7,374.36~ 7,450.71 7,494.27 7,594.79 Spud Date: Start: 2/23/2001 End: Rig Release: Rig Number: 429 Calculation Method: Minimum Curvature S/T # OH v.s. AZ~ (o) -2,021.97! -2,055.13 -2,088.52] -2,120.161 -2,153.58 -2,186.18 -2,218.25 -2,251.16 -2,268.60 -2,282.85 -2,296.91 -2,314.05 -2,331.22 -2,347.51~ -2,362.891 -2,379.271 -2,406.891 -2,421.33i -2,442.461 -2,455.97i -2,473.39i -2,489.89 ~i -2,505.48! -2,537.35i -2,568.56i -2,585.781 -2,625.93! 2,861.10 2,906.93~ 2,953.651 2,998.23] 3,045.04i 3,090.501 3,135.48 3,182.29 3,207.38 3,228.20 3,249.05 3,274.89 3,300.41 3,324.17 3,347.03 3,371.29 3,412.61 3,434.70 3,466.62 3,486.90 3,513.09 3,537.91 3,561.351 3,609.27i 3,655.971 3,681.981 3,743.78 3,503.45i 3,560.01! 3,617.43i 3,672.10 3,729.61 3 785.55i 3,84O.79 3,898.011 3,928.56i 3,953.801 3,978.94 4,009.93 4,040.68i 4,069.50 4,097.04 4,126.31 4,175.99 4,202.37 4,240.63 4,265.00 4,296.45 4,326.24 4,354.38 4,411.91 4,468.06 4,499.25 4,572.90 125.06 DLS BUR (°/lOOff) (°/lOOff) 0.50 0.95 0.21 1.04 0.06 0.35 0.31 0.36 0.37 2.40~ 1.74~ 0.28 1.00; 1.76 0.53 0.83 1.86 1.12 0.74 0.66 1.93 1.27 0.81 0.38 0.35 1.08 1.25 1.40 Type 0.24 MWD -0.66 MWD -0.19 MWD 1.00 MWD -0.02 MWD -0.32 MWD -0.31 MWD -0.31 MWD -0.26 MWD 2.39 MWD 1.48 MWD 0.10 MWD 0.59 MWD -0.40 MWD -0.13 MWD 0.00 MWD -1.56 MWD -0.58 MWD -0.69i MWD -0.53 MWD MWD 0.81 MWD -0.37 MWD -0.35 MWD -1.06 MWD -0.86 MWD 1.40 MWD Printed: 7/23/2001 9:47:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: TMD: 15,325.00 (ft) TMD.... '-.. '' ,., , · OH ~ OH OH OH OH OH OH OH OH OH Oh OH OH OH OH Oh OH OH OH OH Oh OH OH Redoubt Unit #2 Redoubt Unit #2 ORIG DRILLING NABORS ALASKA DRLG NABORS DRILLING TVD: 12,606.52 (ft) Spud Date: Start: 2/23/2001 End: Rig Release: Rig Number: 429 Calculation Method: Minimum Curvature S/T # OH 37.040 36.570 36.49O 36.310 37.940 37.380~ 36.630 36.010 37.080 36.650 37.700 38.750 37.550 36.880 37.430 37.790 38.270 37.420 36.660 37.090 37.780 37.140 36.600 37.050 38.130 38.140 37.650 36.800 123.200 124.040 123.120 122.700 124.990 124.520 123.6501 123.130 123.470 123.550 126.780 127.110 125.120 123.000 123.120 122.790 123.630 121.680~ 121.290 122.590 124.560 123.510 124.800 125.530 127.410 127.140 125.520 125.550 YNN 9,178.61 9,275.04 9,370.88 9,466.19 9,563.20 9,658.90 9,751.16 9,846.85 9,944.35 10,036.60 10,135.63 10,230.37~ 10,323.511 10,420.78! 10,515.76 10,610.85! 10,707.401 10,804.17 10,900.96! 10,994.84i 11,090.08 11,185.09 11,281.74 11,378.31 11,475.64 11,572.20 11,666.86 11,764.04 YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN YNN , YNN NYN NYN NYN NYN NYN NYN NYN 7,671.91, 7,749.12i 7,826.13~ 7,902.841 7,980.19 8,055.951 8,129.63 8,206.73i 8,285.06~ 8,358.86 8,437.78{ 8,512.20 8,585.45 8,662.91 8,738.61 8,813.94 8,889.99 8,966.41 9,O43.67 9,118.77 9,194.40 9,269.81 9,347.14 9,424.441 9,501.561 9,577.51j 9,652.21! 9,729.591 -2,657.73i -2,689.71i -2,721.271 -2,752.00! -2,784.621 -2,817.951 -2,849.07! -2,880.271 -2,912.14i -2,942.70i -2,977.171 -3,012.401 -3,046.32j -3,079.27! -3,110.56 -3,142.13 -3,174.71 -3,206.75 -3,237.20 -3,267.00 -3,299.02 -3,331.37 -3,363.92 -3,397.26 -3,432.55 -3,468.67 -3,503.11 -3,537.28 3,792.62 3,840.73 3,888.26 3,935.74 3,984.35 4,032.39 4,078.37 4,125.69 4,174.221 4,220.36 4,269.25~ 4,316.10 4,362.561 4,411.29! 4,459.37~ 4,508.06i 4,557.83 4,6O7.8O 4,657.52 4,705.32 4,753.55 4,801.43 4,849.42 4,896.73 4,944.47 4,991.91 5,038.75 5,086.59 4,631.15 4,688.90 4,745.93 4,802.44 4,860.97 4,919.44 4,974.96 5,031.61 5,089.64 5,144.96 5,204.78 5,263.37' 5,320.89i 5,379.701 5,437.031 5,495.02 5,554.471 5,613.79i 5,671.98! 5,728.221 5,786.091 5,843.871 5,901.851 5,959.731 6,019.07i 6,078.66 6,136.78 6,195.56 DLS BUR (°/100ft) (°/100ft) 0.191 0.71 0.58 0.32 2.20 0.66 0.99 0.72 1.12 0.47 2.24 1.13 1.84 1.49 0.58 0.43! 0.73i 1.521 0.82~ 0.95 1.45 0.95 0.98 0.65 1.62 0.17 1.17 0.87 Page 5 of 7 -0.08 -O.49 -0.08 -0.19J 1.68 -0.59 -0.81 -0.65 1.10 -0.47 1.06 1.11 -1.29 -0.69 0.58 0.38 0.50 -0.88 -0.79 0.46 0.72 -0.67 -0.56 0.47 1.11 0.01 -0.52 -0.87 ! v.s. AZ~ (o) 125.06 Type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Printed: 7123/2001 9:47:42 AM Page 6 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: TMD: 5,325.00 (ft) Redoubt Unit #2 Redoubt Unit #2 ORIG DRILLING NABORS ALASKA DRLG NABORS DRILLING TVD: 12,606.52 (ft) _._ .: OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH OH 11,858.O0 11,954.051 12,040.59 i 12,135.88 12,231.04! 12,326.00 i 12,421.52 12,515.32 12,607.21 12,704.55 12,796.08 12,893.72 12,989.56 13,083.81 13,181.67 13,276.84 13,372.08 13,469.13 13,562.55 13,658.78 13,755.59 13,851.23~ 13,947.29 ~ 14,042.631 14,137.10[ 14,233.56 14,372.601 14,438.24 36.360 35.320 35.320 35.610 36.780 38.300 39.420 38.44O 38.510 38.630 38.900 38.690 37.880 36.770 37.180 36.870 38.050 37.900i 37.800 37.710i 37.900 38.860 39.430 37.790 38.220 38.910 36.210 i 35.250 J 123.560i NYN 122.4701 NYN 122.470i NYN 120.580i NYN 119.520i NYN 122.0801 YNN 127.240i YNN 127.3501 YNN 127.400i NYN 127.0301 NYN 127.700! NYN 126.690i NYN 126.5801 NYN 127.5701 NYN 128.850i NYN 125.900 NYN 129.030 NYN 129.890 NYN 129.690 NYN 129.970 NYN 129.840 NYN 129.140 YNN 128.670 YNN 129.910 YNN 129.830 YNN 130.610 YNN 130.590 YNN 129.830 YNN 9,805.05 9,882.91 9,953.52 10,031.14 10,107.93 10,183.23 10,257.63 10,330.60 10,402.53 10,478.64 10,550.01 10,626.11 10,701.341 10,776.28i 10,854.471 10,930.45i 11,006.061 11,082.561 11,156.331 11,232.41i 11,308.90i 11,383.871 11,458.37i 11,532.871 11,607.31 11,682.73 11,792.94 11,846.22 Spud Date: Start: 2/23/2001 End: Rig Release: Rig Number: 429 Calculation Method: Minimum Curvature · '.N/;S' .':" -~':'II.-' ' '' · :..: .(ft):....... -3,569.04 -3,599.69 -3,626.55 -3,655.45 -3,683.58 -3,713.22 -3,747.31 -3,783.02 -3,817.72 -3,854.43 -3,889.21 -3,926.19 -3,961.63 -3,996.O7 -4,032.48 .4,067.26 i -4,102.50; -4,140.45 J~ -4,177.14 j -4,214.88 -4,252.95. -4,290.701 -4,328.79! -4,366.451 -4,403.74 -4,442.571 -4,497.72 .4,522.47 i S/T # OH v.s. AZ~ (o) 125.06 5,132.691 6,251.55! 5,179.85i 6,307.75 5,222.061 6,357.73! 5,269.18! 6,412.91 5,317.83I, 6,468.89i 5,367.501 6,526.58i 5,416.741 6,586.46 5,463.631 6,645.361 5,509.071 6,702.48 5,557.40j 6,763.131 5,602.941 6,820.39! 5,651.67 6,881.52 5,699.321 6,940.88 5,744.92i 6,997.99 5,791.16! 7,056.75 5,836.69! 7,114.00 5,882.64i 7,171.86 5,928.74i 7,231.40 5,972.79. 7,288.52 6,018.041 7,347.24 6,063.561 7,406.37 6,109.39! 7,465.57 6,156.58! 7,526.08 6,202.631 7,585.40 6,247.27 7,643.37 6,293.181 7,703.25, 6,357.53! 7,787.61~ 6,386.80i 7,825.78i 1.35 1.27 0.00 1.19 1.39 2.29 3.59 1.05 0.08 0.27 0.551 0.68 0.85 1.34 0.89 1.89 2.35 0.57 0.17 0.20 0.21 1.10 0.67 1.90 0.46 0.88 1.94 1.61 -0.47 -1.08 0.00 0.30 1.23 1.60 1.17 -1.04 0.08 0.12 0.29 -0.22 -0.85i -1.18 0.42 -0.33i 1.24 -0.15 -0.11 -0.09 0.20 1.00 0.59 -1.72 0.46 0.72 -1.94 -1.46 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MMS MMS Printed: 7/23/2001 9:47:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Redoubt Unit #2 Redoubt Unit #2 ORIG DRILLING NABORS ALASKA DRLG NABORS DRILLING TMD: 15,325.00 (ft) TVD: 12,606.52 (ft) · . . .... · S/T::#-i--." TMD ".' AngleT-"T-i'" .." Azimut'h '"' '~-'.'.'CTM '-.. "'. :'...;]'VD '.i i .... "' ~'....' " .'.."';:'.'."..'1.'..' '." ~'. ..... · .(ft).' '.' .('")..' "'"" .(.). ':.. "'.": I'.' · ':' ...' i'. '....:'.....'...(ft). .................................... --....~ .............. :._ .. _.._..... ............. I . .. ........... ". · _ .............. ~ · . ............. ~ ..... · i ; 14,458.64 34.590i 129.480i YNN 11,862.95 i OH ; OH ! OH OH OH OH OH OH OH OH OH OH 14,515.76 14,559.20 14,630.12 14,718.12 14,806.00 14,900.00 15,004.00 15,049.00 15,144.12 15,238.12 15,325.00 34.780 34.030 33.67O 32.210 32.560 31.120 30.280 29.610 27.630 26.O0O 26.000 129.220] 127.750i 125.070i 122.900i 119.9101 114 250[ 107.770i 105.060~ 102.400 103.200 103.200 YNN NYN YNN YNN NYN NYN NYN YNN YNN YNN YNN 11,909.921 11,945.76! 12,004.66. 12,078.521 12,152.73 12,232.61 12,322.05 12,361.05 12,444.55 12,528.43 12,606.52 Spud Date: Start: 2/23/2001 End: Rig Release: Rig Number: 429 Calculation Method: Minimum Curvature -4,529.921 -4,550.53i -4,565.81 -4,589.25 -4,616.01 -4,640.53 -4,663.12 -4,682.17 -4,688.52 -4,699.36 -4,708.75 -4,717.45 6,395.79 6,420.93 6,440.14 6,471.92 6,511.58 6,551.75 6,595.83 6,645.32 6,666.86 6,711.10 6,752.45 6,789.53 7,837.42 7,869.84 7,894.34 7,933.82 7,981.66 8,028.62 8,077.68 8,129.13 8,150.41 8,192.85 8,232.09 8,267.44~ DLS (°/100ft) 3.38 0.42 2.58i 2.17 2.131 1.87 3.53 3.28 3.35i 2.47~ 1.78 0.00 Page 7 of 7 SR' # OH v.s. AZ, (o) 125.06 BUR Type (°/100~) -3.24 ! MMS 0.33i MMS -1.731 MMS -0.51I MMS -1.661 MMS 0.40i MMS -1.53] MMS -0.81 MMS -1.49 MSS -2.08 MSS -1.73 MSS MSS 0.00 Printed: 7/23/2001 9:47:42 AM FOREST OIL CORPORA TiON REDOUBT UNIT #2 REDOUBT SHOALS, PLA TFORM OSPREY UPPER COOK INLET, ALASKA FINAL WELL REPORT May 18, 2001 Lees F. Browne Jr. - Sr. Geologist George Baker-Sr. Geologist Ch~stian Omt-Geologist EPOCH i~,~.,~ Forest Oil Corporation Redoubt Unit #2 FOREST OIL CORPORA TION REDOUBT UNIT #2 PLA TFORM OSPREY, REDOUBT SHOAL UPPER COOK INLET, ALASKA TABLE OF CONTENTS WELL INFORMATION .................................................................................................... 3 DALLY ACTIVITY SUMMARY ......................................................................................... LITHOLOGY AND COMMENTS ................................................................................... 17 MUD RECORD ................................................................... 43 N I RIG TIME DISTRIBUTION ............................................................................................ 55 DAILY MORNING REPORTS ........................................................................................ 06 FINAL LOGS .................................................................................................. APPENDIX EPOCH 2 Forest Oil Corporation Redoubt Unit #2 WELL INFORMATION Company: Forest Oil Corp. Well: Redoubt Unit #2 Field: Redoubt Shoals Region: Cook Inlet Location: Coordinates: Section 14, Township 7N, Range 14W, SM 1918' FSL, 320' FEL Elevation: 90' MSL County, State: Kenai, Alaska APl Index: 733-20501-00 Spud Date: 2/15/2001 Total Depth: 15325' Contractor: Nabors Alaska Drilling Company Representative: Don Jones Mike Murray Rig/Type: Nabors #429 / Platform Epoch Logging Unit: Epoch Personal: #31 George Baker Christian Ornt Lees F. Browne Jr. Company Geologist: Casing Data: Art Saltmarsh 36" landed at 150' 13 5/8" landed at 3,212' 9 5/8" landed at 9,011' 7 5/8" hanging liner landed at 14320' 5 5/8" production liner landed at EPOCH 3 Hole size: Mud Type: Logged Interval: Electric Logging Co: Logs Run at T.D. Forest Oil Corporation Redoubt Unit #2 18 %" to 3226' 12 ¼" to 9026' 8 %" to 14320' 6 %" to 15325' Spud to 3226' LSND to 9026' Oil Based to 15325' Monitor Gas 143' to 7,400' Full Logging 7,400' to 15.325' Schlumberger Caliper-Gamma Ray Array Induction-Density-Neutron-GR Ultra Sonic Borehole Imager EPOCH 4 Forest Oil Corporation Redoubt Unit #2 DALLY ACTIVITY SUMMARY 2/23/01 Rig up. Final rinse to mud pumps, flowline, auger, catch tank, and trip tank. Put on BHA, fill hole, test Diverter, and trip in. Tag at 143'. Spud in at 1700hrs. Drilling from 143' to 168'. Circulate and pull out of hole. Make up Bit #2 and BHA #2. Function test MWD.. 2/24/01 Rig repair. Trip in and resume drilling at 168'. Drill to 567'. Pull out of the hole to flush pits. Dumped 400 bbls of contaminated mud. Drill to 620'. 2/25/01 Drill to 965'. Mud foaming up in pits. Trip out of hole and change out mud to fresh spud mud. Run in hole. Displace hole to new mud. 2/26/01 Continue displacing hole. Resume drilling at 965'. Slide and rotate to 1980'. 2/27/01 Slide and rotate to 2794'. 2/28/01 Drilling from 2794' to 3105'. Circulate bottoms up and pull out of hole. Lay down Sperry tools. Clean stabilizers and bit. Put on 13 3/8" elevators. Put on and make up hanger and landing joint. Lay down and make up BHA and run in hole. 3/1/01 Finish trip in hole. Tag fill at 3095'. Ream 10'. Circulate bottoms up and drill from 3105' to 3226'. Pump sweep and pull out of hole to run casing. Cleaned and change BHA. Rig up to run casings. Run casing. Circulate bottoms up at 1300'. 3/2/01 Run 13 3/8" casing to 3212'. Circulate and condition hole. Put up hanger joint and cement head. Pump first stage cement job with 30 bbls preflush, 223 bbls 12.5 lead, 171 bbls 15.8 tail. Bump plug with 3365 strokes. Circulate hole clean of cement. Circulate and wait on cement. Pump second stage cement job with 40 bbls preflush, 530 bbls 12.5 lead- 95.5 bbls 15.8 tail. Bump @ 2150 strokes. Close DV tool and check for flow. Rig down cement head and wash up. 3/3/01 Lay down landing joint and clean. Lay down casing tools. Nipple down diverter system. Nipple up BOP. 3/4/01 Finish nipple up BOP. Change Rams and test BOP. Put on BHA and run in hole. Tag cement at 2000'. Drill cement to 2017'. Circulate hole clean. Test stage collar. Drill out collar. Wash and ream to 2216'. Circulate hole clean. Test casing. Run in hole to 2694'. Circulate out thick mud. Run in hole. EPOCH Forest Oil Corporation Redoubt Unit #2 3/5/01 Circulate and condition mud. Trip in hole and tag cement at 3106'. Drill to 3106' and circulate and condition mud. Test casing and drill landing collar at 3128'. Drill shoe and 20' of new hole. Circulate bottoms up and conduct leakoff test. E.M.W. was 14.1 ppg. Resume drilling from 3246'.. 3/6/01 Continue drilling ahead with surveys each stand. Short trip to shoe. Work tight spot at 3468' to 3364'. Service rig. Resume drilling from 4750'. 3/7/01 Drilling from 5306' to 6103'. Circulate sweep around. Circulate hole clean. Monitor well. Pump dry job. Pull out of hole to 3172'. Service rig. Cut and slip drilling line. Put on 5" drill pipe. Break circulation at 4690'. Run in hole. No fill. Wash 90' to bottom. Drilling from 6103'. 3/8/01 Drilling from 6150' to 7159'. Mix and pump high viscosity sweep around. Circulate hole clean. Monitor well. Prepare for scheduled short trip to shoe. 3/9/01 Circulate hole clean. Short trip to shoe. Service rig. Cut and slip drilling line. Trip in hole. Hole conditions were good with no tight sections. Drilling from 7160' to 7580'. Pump sweep around. Short trip to 6000'. Service top drive. Run in hole. Run in hole. No fill at bottom. Hole was slick in and out with no tight sections. 3/10/01 Resume drilling from 7580' to 7830'. Circulate sweep around. Circulate hole clean. Monitor well. Pump dry job. Pull out of hole for new bit and BHA. Hole was slick pulling out. Rig up to test BOP's. Test BOP's. 3/11/01 Test BOP's and clear rig floor. Run in hole. Service rig and top drive and shoe. Run in hole and wash and ream from 7736' to 7832'. No tight hole and no fill. Drilling from 7832' to 7945'. 3/12/0 1 Drilling ahead to 8165'. Work on pumps. Drilling from 8165' to 8211'. Pump sweep around. Circulate hole clean. Monitor well. Short trip to the shoe with no tight sections. Work on pumps. Run in hole to 8117'. Break circulation and wash and ream to bottom. Hole was slick. Drilling from 8211' to 8274'. 3/13/0 1 Drilling from 8274' to 8487'. Circulate bottoms up to clean hole. Monitor well. Pump dry job. Pull up hole and monitor well at shoe. Trip out o hole. Change out Bit #4 and trip in hole. 3/14/01 Trip in hole to shoe. BOP drill. Service top drive. Continue tripping in hole. Wash and ream 80' to bottom. Hole was slick with no fill. Resume drilling from 8494' to 8835'. [:1 EPOCH 6 Forest Oil Corporation Redoubt Unit #2 3/15/01 Drilling from 8835' to a total depth of 9029'. Circulate sweep around. Monitor well. Pump small dry job. Short trip 6 stands. Minor tight spot at 8600' to 8560'. Took 40k going thru same tight sport going back in. Run in hole and circulate high viscosity sweep around. Monitor well. Pump dry job. Pull out of hole for E-logs. 3/16/0 I Log hole with E-logs. Rig down logging tools. No problems with wire line tools. Put on BHA and run in hole to shoe. Cut and slip drilling line. Service top drive. Run in hole to 8971'. Wash 50' to bottom. Pump sweep around, Hole not cleaning up as last trip. Condition mud and short trip. Circulate high viscosity sweep around. Circulate hole clean. Spotted 150 bbls of soltex treated mud on bottom. Pump dry job. Pull out of hole for casing. 3/17/01 Continue to trip out of hole. Lay down BHA. Floor hand injury. Shut down rig. Medivac injured floor hand. Post accident evaluation. Continue to lay down BHA. Clean out rams to 9.625". Test doors. Clean out top drive bales. Rig up casing crew. Run casing. 3/18/01 Run casing and cement well. Make up oil-base mud system in pits. 3/19/01 Wait on cement. Rig down landing joint and set pack off. Testing BOP's. Drain stack and fill with Versa Drill. 3/20/01 Make up BHA and run in hole with BHA. Pick up pipe and continue to run in hole. 3/21/01 Finish running in hole and tag cement. Drill out cement and test casing to 3000 psi. Drill out shoe and drill out 10' of new hole. Perform FIT. Good test. Drill out 8.5" hole with no problems. Taking drill cuttings to Swaco Injection slurry tanks. 3/22/01 Drilling with no problems to 10255'. 3/23/01 Drilling ahead with no formation problems. Short trip to shoe to do rig service. Tight spots encountered during short trip. Tight spots required back reaming. Increase mud weight. Run in hole to bottom with no problems. Resume drilling formation. 3/24/01 Drilling ahead to 11194' with no problems. 3/25/01 Drill ahead with no hole problems. Drill to 11249'. Trip out for new bit. Put on new bit #7 and BHA and trip in hole. Resume drilling. 3/26/01 Drilling ahead with no hole problems. Pumping sweeps every 150' to 200'. Short trip 8 stands with no problems. Run in hole to bottom with no problems. Resume drilling. EPOCH 7 Forest Oil Corporation Redoubt Unit #2 3/27/01 Drilling ahead. Drill to 12234'. Circulate bottoms up. 3/28/01 Begin to pull out of the hole for bit trip. 3/29/01 Pull out of the hole. Change pulsator in MWD. Stand back BH^, Test BOP, pick up BHA and new bit, pick up 5" drill pipe. Run in hole and ream 30" to bottom. Drill to 12239'. Circulate bottoms up and clean the hole. Drill ahead. 3/30/01 Drill ahead to 12671'. Service the rig. Drill ahead. 3/31/01 Drill to 12815'. Circulate the hole and pull out of the hole. Becoming tight at 12135'- 11800'. Circulate and ream the hole. Tight at 11545- 11505'. Continue to pull out of the hole. Change bit and motor. Run in the hole to 9005'. Cut drilling line and continue to run in the hole. 4/1/01 Continue to trip into the hole to 12449'. Ream to 12815'. Hard reaming. Circulate the hole. Drilling to 13091'. Had a problem sliding, could not get weight to the bit. 4/2/01 Drilled to 13255'. Circulate sweep and pull out of the hole. Pump tight spots at 12990 - 12627' (50K over normal), tight at 12124 - 12000', tight at 10850 - 10840. Finish pulling out of the hole. Change bit and begin to run into the hole. 4/3/01 Circulate at the shoe. Circulate and was down from 12750 to 13137'. Circulate and then drill from 13255'. 4/4/01 Drill formation to 13684'. Circulate bottoms up and short trip. Pulled 50-60K over from 13550- 13424, pumped out 13424- 12850', tight @ 13100 & 13040 going back into the hole. Break circulation - stage up pump - wash & ream 55 feet to bottom. Drill ahead. 4/5/01 Drill to 13823'. Circulate sweep and pull out of the hole. Pump out 12 stands. Change bit and BH^. Test BOPE. Run in hole with new bit and BHA. Wash to bottom and circulate bottoms up before drilling ahead. 4/6/01 Drill to 14196'. Pick up 3 joints of drill pipe. Wiper gas = 57 units. Drill ahead. 4/7/01 Drill ahead to 14320'. Circulate bottoms up and pull and pump 12 stand short trip. Circulate out 227 units of Wiper Gas. Hole is tight. Circulate bottoms up again and pull pipe back to the shoe at 9011'. Cut and slip drilling line. Run in hole to bottom and ream tight spots. Circulate out 230 units of Wiper Gas. EPOCH 8 Forest Oil Corporation Redoubt Unit #2 4/8/01 Pull out of the hole with Bit #11. Stand back BHA, clean rig floor and rig up Schlumberger. Begin to run wire line logs. Tools will not go past 9120'. Pull tools out of the hole and change centralizer and add a knuckle joint. Run tools into the hole. Tools will not go past 9120'. Pull tools out of the hole and tool is shortened. Run tools into the hole and they will not go past 9120'. Begin to pull tools out of the hole. 4/9/01 Finish pulling tools out of the hole. Rig down Schlumberger and clean rig floor, change BHA and rerun Bit #11. Run into the hole to 9100'. Ream tight spots and pull into the shoe and circulate out wiper gas = 147 units. Wash area three times and run to bottom. Circulate and sweep hole clean = 500 units of Trip Gas. Pull up to the shoe and ream out at 9100'. Pull out of the hole and prepare for wire line logs. 4/10/01 Make up wire line tools and run in the hole and log with various tool sizes. Finish logging and run in the hole with BHA and HWDP (rrBIT #11). 4/11/01 Run in the hole to 8972'. Circulate mud and cut and slip drill line. Continue to run into the hole, becoming tight at 112300' and 13200'. Wash and ream to bottom. Circulate bottoms up. Trip gas = 458 units. Pull a seven stand short trip. Run back down to 13850'. Wash and ream down at 13850' and ninety feet to bottom. Circulate and sweep hole. Wiper gas = 128 units. Pull up to 13175'. Hole tight at 14290'. Run back in the hole with hole again becoming tight at 14290'. Circulate and sweep hole. Wiper gas = 75 units. Pull up to 13700'. Hole tight at 14290'. Run back in with no fill. Circulate and pump hi-vis sweep. Wiper gas = 30 units. Pull out of the hole (tight at 14290') and prep for running casing. 4/12/01 Change bottom rams, test doors-seals. Install with bushings and lay test stands. Rig up and run 7 5/8" casing. Run in 135 joints. Pick up and make up hanger and run into the hole one stand, 5" hanger in 9 5/8" hole. Shoe is at 5629'. Circulate liner (vol = +40 SPM, 3.4 bbl/min at 800 PSI). Circulate out 113 units of gas. Continue to run casing in the hole. 4/13/01 Finish running in the hole with liner to TD. No problems with hole sticking. Hold pre-job safety meeting and test lines to 2500 psi. Batch mix cement and pump 10 bbls of water, 30 bbls of space/surf. 34.5 bbls of cement. Chase and displace with 416 bbls of active mud. Bump plug with BJ unit and compression set liner packer/hanger. Test liner top and casing to 3000 psi and pull out of the hole two stands. Pull out of the hole and lay down drill pipe. 4/14/01 Finish laying down drill pipe. Run in the hole with 5" drill pipe out of the derrick (45 stands). Lay down and unload boat. Test choke manifold, floor valves and upper kellycock valves. Run in the hole with 5" drill pipe. Change out bottom rams to 3.5". Pull wear bushings. Set test plug, test 5" EPOCH 9 Forest Oil Corporation Redoubt Unit #2 rams, kill lines and chase valves. Pick up 3.5" test joint and test 3.5" pipe and annular. Pull test plug and set wear ring. 4/15/01 Finish testing BOPE. Lay down tools. Pick up BHA. Strap and pick up 3.5" HWDP and 3.5" drill pipe. Service rig. Circulate mud. Run in the hole with 5" drill pipe. Tag cement at 14175'. Drill cement to 14234'. Circulate bottoms up (116 units). Pressure test casing and drill out landing collar. 4/16/01 Finish drilling out landing collar, float and shoe. Drill formation from 14320' to 14345'. Leak off test to 10.5 MWE. Drill formation from 14345' to 14400'. Circulate out samples. Drill formation from 14400' to 14420'. Circulate out samples. Pull out of the hole for Core #1. 4/17/01 Finish pulling out of the hole. Lay down BHA and remove from the rig floor. Pick up core barrel. Space out inner core barrel. Test CSS survey tool. Run in the hole with BHA. Pick up 9 joints of 4 %" DC. Run in the hole with 3.5" drill pipe. Cut and slip drill line. Service rig. Run in the hole and wash to bottom. Begin coring at 14420'. 4/18/01 Core to 14440'. Core jam. Pull up to 14310', drop dart and pump dry job. Pull out of the hole. PJSM stand back drill collars and lay down inner core barrel. Recovered 14' of core. Pick up new inner core barrel and make up new barrel.. Install ESS survey. Run in the hole with BHA and 3.5" drill pipe. Service the rig. Run in the hole and wash 30' to bottom. Begin coring from 14440' to 14475'. Begin to pull core out of the hole. 4/19/01 Pull up to the shoe. Drop dart and pump dry job. Pull out of the hole. Hold a pre job safety meeting before trip out and laying down the core. Make up the new bit and orientate survey tool. Recovered 34.5' of 35" drilled. Run in the hole with 3.5" drill pipe. Service the rig and continue to run in the hole. Wash 20' to bottom. Core from 14475' to 14537', Survey hole and back ream out of the hole (tight). 4/20/01 Pull out of the hole with core # 3 to the shoe. Drop dart and pump dry job. Pull out of the hole. Stand back BHA. Hold pre job safety meeting. Lay down the inner core barrel. Make up new inner core barrel. Hold pre job safety meeting and run in the hole. Service the rig and continue to run in the hole with 3.5" drill pipe. Cut and slip 90' of new drill line. Run in the hole and wash 100' to bottom with 3' of fill. Core ~ from 14537' to 14558'. Core jammed. Drop circulate dart and pump mud to sub. Begin to pull out of the hole with core ~4. 4/21/01 Pull out of the hole with Core #~. Stand back BHA. Hold pre job safety meeting. Lay down Core #.4. Run in the hole with 3.5" drill pipe. Service rig. Run in the hole and ream 25' to bottom. Core from 14458' to 14567'. Core Jammed. Pull up and drop dart, circulate sub. EPOCH 1 o Forest Oil Corporation Redoubt Unit #2 4/22/01 Trip out of the hole with 5" drill pipe and Core # 5. Pull out of the hole. Work BH^ and lay down By-Pass sub and one joint of drill pipe. Hold pre job safety meeting. Lay down core, break bit and make up new bit. Dress core barrel and stand back. Pull wear ring bushing and set test plug. Test 5" rams, 3.5" rams, blind rams, mud cross valves, choke manifold valves, top drive valves and floor valves. Pick up BHA and hold PJSM. Run in the hole. Cut and slip drill line. Continue to run in the hole with bit #12rr2. 4/23/01 Clean rig floor and continue to run in the hole with Bit #12rr2. Wash and ream from 14320' to 14567'. Drill formation from 14568' to 14594'. Circulate bottoms up, mix and pump sweep, drop survey and pull to the shoe. Drop dart and open circulating sub. Pump dry job and service the rig. Begin pulling out of the hole. 4/24/01 Trip out with 3.5" drill pipe. Lay down By-pass sub and remove dart. Pull out of the hole with the BHA. Hold pre job safety meeting. Retrieve multi shot survey and lay down drilling BHA. Clean-rig floor and hold pre job safety meeting. Make up core BHA and run in the hole with 3.5" drill pipe. Change out 3.5" handling tools to 5". Trip in the hole with 5" drill pipe. Service the rig and continue to run in the hole with 5" drill pipe. Wash and ream to bottom. Bit plugged, stand back 3 stands and circulate slowly at the shoe. Cleaned out plugged string and wash from 14320' to 14563'. Ream from 14563' to 14594'. Begin coring from 14594'. 4/25/01 Core to 14621'. Pull out of the hole. Hole is tight at 14595'. Pump bypass dart down and pump dry job. Trip out of the hole with 5" drill pipe to 8073'. Change out 5" handling tools to 3.5". Trip out with 3.5" drill pipe. Pull out of the hole. Lay down core barrel and dress new barrel. Set ESS survey tool. Run in the hole with 3.5" drill pipe. Run in the hole with 5" drill pipe. Wash from 14350' to 14600', ream from 14600' to 14621'. Begin core at 14621 '. 4/26/01 Core to 14674'. Pull out of the hole to 14315'. Drop dart and pump down dry job. Trip out with 5" drill pipe. Change out 5" handling tools to 3.5" and trip out with 3.5" drill pipe. Lay down core barrel and pick up new core barrel and bit. Set ESS survey tool. Run in the hole to the shoe. Cut and slip 90" of new drill line. Circulate mud and begin to work on top drive. 4/27/01 Finish work on top drive and trip in hole. Wash and ream from 14566' to 14674'. Wipe out tight spots at 14644' and 14655'. Core from 14674' to 14689'. Pull out of the hole to 14284' with no problems. Drop dart and pump dry job. Trip out of the hole with 5" drill pipe. Lay down one joint of drill pipe and change out %' handling tools to 3.5". Pull out of the hole with core #8. Lay down core barrel and break the bit off. Stand back EPOCH ] 1 Forest Oil Corporation Redoubt Unit #2 core barrel and clean floor and service the rig. Rig up E-line and pick up tools. Run in the hole with wire line logs. 4/28/01 Finish wire line logging and rig down wire line tools. Hold a pre job safety meeting and then make up new drilling assembly. Run in the hole with 3.5" drill pipe. Change out 3.5" handling tools to 5" and run in 5" drill pipe to 14312'. Circulate and shear the drilling mud. Install blower hose and run in the hole, SLICK from 14312' to 14595'. Wash and ream 94' to the bottom of the hole. Circulate and shear mud and stage up pump rate. Drill (slide) ahead from 14689'. 4/29/01 Drill to 14727'. Pull pipe to shoe (14320) for preparation to work on the top drive. Clean the rig floor and hold pre job safety meeting. Remove top dive traction motor and drain fluids. Disconnect hydraulic hoses and electrical lines. Remove front of protection guard and torque boost. Loosen bolts on traction motor. Remove spark arrester and prepare to unpin blocks from top drive. Circulating mud through the choke manifold with returns to the pits with the annular closed throughout top drive repair. Change and install armatures and brushes. Hold pre job safety meeting. Rig and pick and spot crane to reinstall top drive motor. Service rig with various fluids. 4/30/01 Finish installing torque boost hook-up, hydraulic hoses and spark arrestor. Install front protection guard and make up electrical lines and safety wire all hex bolts. Install oil, blower hose, bleed off air and make up electrical lines. Function test the operation of traction motor and top drive. Set armature and dressing brushes. Found flashing at the bottom of the armatures. Wait on orders while circulating mud at 10-12 spm. Prepare the first motor for shipping. Clear work area and secure lock out-tag outs. Begin removal of quads, safety wires, drain gear box and disconnect equipment for access removal of junk traction-motor. Change out armatures and components and transfer accessories for fresh motor installation. 5/1/01 Continuing to monitor the well periodically by circulating drilling mud at 10-12 spm. Change out armatures and components and transfer accessories. Finish fresh motor installation and pre heat new pinion gear for installation on motor. Run a test of the traction motor, set brushes, check bearings and hold pre job safety meeting. Pick and spot the crane, stab and install the motor on the top drive. Check and shim gear lash and alignment perimeters and toe in. Torque monitor bolts and install safety wires and keepers. Install torque boost, spark arrestor, hydraulic and electrical lines. Fill the gearbox and hold pre job safety meeting. Install guards, spacers and keepers. Safety wire gear oil and fill brake fluids. Double check for overhead tools and clean up and wipe down for possible leaks. Inspect brakes and linkage. Cut and slip 38' of new drill line. EPOCH 12 Forest Oil Corporation Redoubt Unit #2 5/2/01 Finish making up electrical lines on top drive. Bleed air off top drive brakes. Install blower hose and test function operation of traction motor and top drive. Remove torque boost and clean out broken piston dogs and bearings. Wait on new piston dogs and bearings. Install new piston dogs and bearings to torque boost and install top drive. Function test the operation of the traction motor and top drive. Run in the hole from the shoe and wash 35' to bottom. Hole is slick and had no fill. Drill formation from 14727' to 14740'. Circulate bottoms up and continue to drill formation to 14800'. Circulate bottoms up and prepare to pull out of the hole. 5/3/01 5/4/01 Drop and pump multi shot survey down the hole. Pull out of the hole to 14251' and drop bypass dart and pump down. Pump dry job and remove top drive blower hose. Monitor the well and clean excess oil base mud from the rig floor. Begin to pull out of the hole with the 5" drill pipe. Change over 5" handling tools to 3.5" and trip out with 3.5" drill pipe. Pull out of the hole with BHA and lay down the drilling assembly. Hold a pre job safety meeting and make up test joints, cross over spacers and pump sub. Pull wear ring, reverse dress and seat plug. Fill the stack and test hydraulic 3.5" rams, blinds, manual kill, choke, 5" rams and manual IBOP. Pull plug and set wear ring. Lay down test joints and clean the rig floor. Hold a pre job safety meeting and rig up wire line logs. Run in the hole with wire line logs and log. Pull logs out of the hole and hold a pre job safety meeting. Begin injection testing. Finish injection testing and rig up wire line logs. Run temp log. Rig down wire line loggers and make up core #9 assembly and begin to run into the hole. Trip in with 3.5" drill pipe and monitor the well at 8077'. Break circulation and change over to 5" handling tools. Trip in the hole with 5" drill pipe. Monitor the well at 11,100' and 14252'. Wash and ream from 14320' to 14800'. Begin to core at 14800'. 5/5/01 Core formation to 14844'. Break the core and monitor the well. Lay down drill pup and two singles. Pull up to the shoe and monitor the well. Drop dart and pump down followed by dry job. Remove blower hose and begin to pull out of the hole with core #9. 5/6/01 Pull out of the hole with core #9. Lay down BHA and hold pre job safety meeting. Lay down the core and make up Core #11. Make up BHA and survey tool. Run into the hole to 14750'. Wash and ream to bottom and shear mud. Begin coring at 14844'. 5/7/01 Core the hole to 14898'. Monitor the well, drop survey and pull out of the hole to 14240'. Drop dart and pump dry job and begin to pull out of the hole. Hold a pre job safety meeting and lay down the core barrel. Make up a new core barrel and load survey instrument. Run in the hole with the BHA and drill' pipe to 8800'. Run BOP drill and hold pre job safety meeting. Cut and slip 104' of new drill line. Run in the hole to 14795'. Wash and EPOCH ] 3 Forest Oil Corporation Redoubt Unit #2 ream to bottom. Begin coring at 14898' and core to 14912'. Circulate and monitor the well. Begin to pull out of the hole with core #11. 5/8/01 Pull out of the hole to the shoe and drop dart, pump dry job and monitor the well. Pull out of the hole and lay down the BH^ and hold a pre job safety meeting. Lay down the core and change out the core bit. Pick up and orientate new inner core barrel. Service the top drive by draining the gear oil and checking the bearings. Make up the BH^ and run in the hole with drill collars and HWDP. Run in the hole with 3.5" drill pipe to 8710' and monitor the well. Circulate the drill mud and install air slips and change out the top drive lube filter. Run in the hole with 5" drill pipe to 14250' and circulate to shear mud and monitor the well. Wash and ream 95' to bottom. Top drive is making noise so pull back drill pipe to 7 5/8" casing to address the problem. Remove top drive torque boost drive gear and shear and reinstall motor. Run in the hole to bottom and begin to core #12 at 14912'. 5/9/01 Core to 14935': core jams. Break core off and monitor the well. Pull pipe up into the casing; drop dart, open ports, pump dry job, blower hose off and air slips. Pull out of the hole to 8077'. Monitor the well and change handling tools from 5" to 3.5" and continue to pull out of the hole. Hold a pre job safety meeting and lay down the core. Change the bit and make up a new core barrel. Change thrust bearing and orientate shoe. Orientate and load survey tool. Monitor the well and begin to run in the hole with Bit #2t to core #13. 5/10/01 Run in the hole to 8100' and circulate drilling mud. Run in the hole to 14260' and circulate drilling mud. Hold a pre job safety meeting and cut and slip new drilling line. Service the rig and install blower hose, as well as, work on top drive. Run in the hole to bottom and core from 14935' to 14968'. Monitor the well after coring and pull back into the casing. Drop dart and circulate drilling mud and open ports. Monitor the well and pump a dry job. Remove the blower hose and pull out of the hole with 5" drill pipe to 8077'. Monitor the well and change out handling tools from 5" to 3.5" and continue to pull out of the hole. Pull survey tool and lay down core barrel #13. 5/11/01 Hold a pre job safety meeting and then lay down core #13. Test BOP's. Install wear ring and make up new core bit and barrel. Orientate the survey tool and run in the hole to 8100'. Circulate drilling mud and continue to run in the hole to 14250'. Monitor the well and service the top drive. Shear drilling mud and wash/ream to the bottom of the hole (60'). Core from 14968 to 14978'. Circulate the drilling mud and monitor the well. Pull up into the casing and drop dart, pump and open ports, then pump a dry job. Pull out of the hole with 5" drill pipe to 8077'. Change over handling tools from %' to 3.5" and continue to pull out of the hole with core #14. EPOCH ] 4 Forest Oil Corporation Redoubt Unit #2 5/12/01 Finish pulling out of the hole with core #14. Hold a pre job safety meeting and then lay down the core barrel. Change out the survey tool and orientate new tool. Change out the core bit and begin to run into the hole. Run in the hole to 8100' and circulate the drill mud. Run into the hole to 14250' and circulate the drilling mud. Wash and ream to 14978' with no hole fill. Core from 14978' to 15000'. Pull out of the shoe to the shoe. Hole is tight just below the shoe. Drop dart and shear circulating sub. Pump a dry job and monitor the well. Begin to pull out of the hole with core #15. 5/13/01 Pull out of the hole and hold a pre job safety meeting. Remove survey tool and lay down the core barrel. Make up new core barrel and orientate survey tool. Break the bit and inspect it for condition. Hold a pre job safety meeting and pick up survey tool and make up BHA. Run in the hole to 8150 and establish circulation. Run in the hole to 14320' and cut and slip 320" of drill line. Service the rig and inspect crown and block sheers. Run in the hole and circulate mud at 14925'. Ream 25' to bottom and begin core #16 at 15000'. 5/14/01 Core from 15000' to 15047' and survey the hole. Monitor the well and begin to pull out of the hole with core #16. Pull to 14250' and drop dart and pump dry job, Pull out of the hole and lay down survey tool and hold a pre job safety meeting. Lay down core #16 and pick up a new core barrel. Change out the bit and run in the hole with the BHA and hold a BOP drill. Clean the rig floor and service the rig. Run in the hole with 3.5" drill pipe and change over to 5" drill pipe. Run in the hole to the shoe and circulate drilling mud. Run in the hole to 14925' and circulate to 15000'. Ream from 15020' to 15047' (no fill). Core #17 from 15047' to 15060'. 5/15/01 Survey the hole and monitor the well, then pull up to 14239'. Drop dart and pump dry job, then begin to pull out of the hole. Hold a pre job safety meeting and lay down survey tool. Lay down the core barrel and pick up a new core barrel. Orientate survey tool, check the bit and service the rig. Run in the hole with 3.5" drill pipe. Circulate and shear the drilling mud at 8150'. Change out to 5" handling tools and run in the hole with 5" drill pipe to the shoe. Cut and slip 75" of new drill line. Hold a pre job safety meeting and run in the hole and circulate the drilling mud at 15036'. Ream from 15036' to 15060' and begin to core #18 at 15060'. 5/16/01 Core from 15060' to 15088'. Back ream out of the hole from 15080' to 15058'. Pull out of the hole to 14275'. Drop dart and pump dry job. Monitor the well before pulling out of the hole. Lay down jars, survey tool and core barrel. Service the rig and pick up the new BHA. Run in the hole with 3.5" drill pipe. Break circulation and shear mud and change over to 5" drill pipe handling tools. Run in the hole to the shoe and circulate and shear drilling mud. Run in the hole to 14489',"tight". Ream hole from 14489' to 14817'. EPOCH ] 5 5/17/01 5/18/01 Forest Oil Corporation Redoubt Unit #2 Ream to the bottom of the hole at 15088' and drill ahead. Drill to 15254' and circulate drilling mud before short trip. Pull out of the hole for wiper trip to 14320'. Hole is tight at 14435' to 14400'. Service the rig and check crown while circulating drilling mud and monitoring the well. Run in the hole to bottom with the hole being tight at 14416'. Ream from 14410' to 14460' to wipe out ledge. Run to bottom without any fill. Drill formation from 15254' to 15325'. Circulate and condition the hole and monitor the well. Short trip to the shoe and run to bottom without fill. Condition hole for E-logs and monitor the well. Drop dart and pull out of the hole to run E-logs. Total Depth = 15325'. EPOCH ] 6 Forest Oil Corporation Redoubt Unit #2 LITHOLOGY AND COMMENTS NOTE: ALL LITHOLOGY DESCRIPTION COLORS TAKEN FROM THE ISCC=NBS ROCK COLOR SYSTEM. BEGIN LOGGING LITHOLOGY AT 7400' AT 17:00 HOURS ON 03/09/01. 7405' SAND = LIGHT GRAY TO MEDIUM LIGHT GRAY WITH MEDIUM GRAY SECONDARY HUE; UPPER FINE TO LOWER FINE WITH INDIVIDUAL GRAINS OF VERY COARSE UPPER; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUNDED; LOW TO MODERATE SPHERICITY; DOMINANTLY QUARTZ SAND WITH TRACES OF LITHIC FRAGMENTS, INDIVIDUAL GRAINS RANGE FROM TRANSPARENT TO TRANSLUCENT; MATRIX SUPPORTED; TRACE CARBONACEOUS MATERIAL PRESENT. 7465' COAL = GRAYISH-BLACK TO BLACK; DENSE TO BRITTLE; PLANAR TO CONCHOIDAL FRACTURES; MASSIVE CUTTING HABIT; METALLIC TO VITREOUS LUSTER, OCCASIONALLY WAXY; SMOOTH TO CLAYEY TEXTURE; THIN BEDDING STRUCTURE. 7500' SAND = MEDIUM LIGHT GRAY TO MEDIUM GRAY; LOWER MEDIUM TO UPPER FINE; POOR TO FAIR SORTING; SUBROUNDED TO ROUNDED; FAIR TO MODERATE SPHERICITY; DOMINATLY QUARTZ WITH GRAINS BEING TRANSPARENT TO WHITE TRANSLUCENT; GRAIN SUPPORTED; NO OIL INDICATORS. 7540' SANDSTONE = PREDOMINANTLY LOOSE GRAINS; TRACE AMOUNTS OF LIGHT GRAY PRESERVED SS; LOWER MEDIUM TO FINE GRAINED; SUBROUNDED; FAIR TO MODERATE SPHERICITY; MODERATELY WELL SORTED; GRAIN TO MATRIX SUPPORTED; CLAY/ASH MATRIX; 90% QUARTZ, 10% CHERT; NO OIL OR SAMPLE SHOWS; POOR SAMPLE QUALITY. 7600' COAL = BLACK; MODERATELY HARD TO DENSE; PLANAR TO CONCHOIDAL FRACTURE; PLATLY TO FLAKY CUTTINGS HABIT; SLIGHTLY VITREOUS TO DULL LUSTER; ROUGH TEXTURE; INTERBEDDEDWITH CLAYSTONE. 7630' TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT; GUMMY; POORLY PRESERVED; MASSIVE CUTTINGS; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE. 7655' SANDSTONE = PREDOMINANTLY LOOSE GRAINS; TRACE AMOUNTS OF LIGHT TO VERY LIGHT GRAY PRESERVED SPECIMENS; ABUNDANT TRANSLUCENT TO TRANSPARENT GRAINS; SOME WHITE TO LIGHT GRAY LOOSE GRS; UPPER MEDIUM TO LOWER FINE GRAINED; ANGULAR TO [:l EPOCH 17 Forest Oil Corporation Redoubt Unit #2 SUBROUND; MODERATELY SPHERICITY; MODERATELY WELL SORTED; MATRIX SUPPORTED WITH TRACE AMOUNTS OF WHITE ASH AND CLAY MATRIX IN SAMPLES; 80% QUARTZ, 20% CHERT; MINOR AMOUNTS OF BLACK CARBONACEOUS MATERIAL; NO OIL INDICATORS. 7715' COAL = BLACK; TOUGH TO BRITTLE; PLANAR SPLINTERY FRACTURE; PLATY CUTTINGS HABIT; SLIGHTLY VITREOUS LUSTER; ROUGH TO OCCASIONALLY SMOOTH TEXTURE; OCCURS AS ABUNDANT CAVED SPECIMENS. 7745' NOTE: POOR SAMPLE QUALITY, ABUNDANT COAL AND LOOSE SAND. 7760' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; SOFT TO CRUMBLY; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; OCCASIONAL CARBONACEOUS LAMINATIONS; GELATINOUS TO MUSHY CONSISTENCY. 7795' SAND = MEDIUM GRAY TO MEDIUM DARK GRAY; UPPER MEDIUM TO LOWER MEDIUM; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; DOMINANTLY QUARTZ WITH CHERT AND LITHIC FRAGMENTS PRESENT; MATRIX SUPPORTED; COMMON CARBONACEOUS MATERIAL PRESENT; NO OIL INDICATORS PRESENT. 7860' COAL = BLACK; TOUGH; BRITTLE IN PART; BLOCKY TO PLATY CUTTINGS; BLOCKY FRACTURE; SLIGHTLY VITREOUS LUSTER; SMOOTH TEXTURE; MASSIVE. 7885' SANDSTONE = REPRESENTED BY LOOSE CLEAR TO TRANSLUCENT QUARTZ GRAINS; TRACE AMOUNTS OF GRAY CHERT AND WHITE GRAINS; LOWER MEDIUM TO FINE GRAINED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; MODERATELY WELL SORTED; NO MATRIX PRESERVED; PROBABLY CLAY MATRIX; NO OIL INDICATORS. 7930' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; MUSHY TO GELATINOUS CONSISTENCY; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE. 7960' SAND/SANDSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; LOWER MEDIUM TO UPPER FINE; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; 70% CLEAR TO TRANSLUCENT QUARTZ, 30% CHERT AND LITHIC FRAGMENTS; MATRIX SUPPORTED; COMMON BLACK CARBONACEOUS MATERIAL PRESENT; NO OIL INDICATORS PRESENT. EPOCH ] 8 Forest Oil Corporation Redoubt Unit #2 7990' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; MUSHY TO GELATINOUS; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MODERATELY TO LOW COHESIVENESS; MODERATE ADHESIVENESS. 8045' COAL = GREENISH-BLACK TO BLACK; DENSE TO BRITTLE; BLOCKY TO PLANAR FRACTURE; PLATY CUTTINGS HABIT; VITREOUS TO WAXY LUSTER; SMOOTH TO SILTY TEXTURE; THIN BEDDING STRUCTURE. 8075' SANDSTONE = PRESERVED AS LOOSE CLEAR TO TRANSLUCENT QUARTZ GRAINS; MINOR AMOUNTS OF LIGHT GRAY TO WHITE GRAINS; PREDOMINANTLYFINE GRAINED W/MINOR AMOUNTS OF LOWER MEDIUM QUARTZ GRAINS; MODERATELY WELL SORTED; SUBANGULAR TO SUBROUNDED; VARIABLE AMOUNTS OF CHERT; PROBABLY GRADES TO SANDY CLAYSTONE; NO MATRIX PRESERVED; NO OIL INDICATORS. 8120' COAL = BLACK TO BROWNISH BLACK; SLIGHTLY TO MODERATELY HARD; BRITTLE; PLATY TO WEDGELIKE CUTTINGS; PLANAR TO CONCHOIDAL FRACTURE; SLIGHTLY RESINUOUS TO WAXY LUSTER; SMOOTH TO MATTE TEXTURE; SOME VISIBLE GAS BLEEDING. NOTE: GAS INCREASES FROM 8150' TO 8180' REPRESENT SWAB GAS FROM THE ABOVE COAL INTERVAL. VERY POOR SAMPLE QUALITY PRESENT IN THIS SECTION. NOTE: WIPER TRIP AT 8210'. 8205' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; SOFT TO MUSHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE BEDDING STRUCTURE; COMMON CARBONACEOUS MATERIAL PRESENT. 8245' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY; SOFT TO OCCASIONALLY FIRM; ABUNDANT MUSHY SPECIMENS; MASSIVE TO SLIGHTLY PLATY CUTTINGS IRREGULAR FRACTURE; DULL EARTHY LUSTER; CLAYEY TO SLIGHTLY SILTY TEXTURE; SLIGHTLY CARBONACEOUS. 8280' COAL = BLACK; FIRM TO MODERATELY HARD; PLATY TO SCALY CUTTINGS; PLANAR FRACTURE; SLIGHTLY RESINOUS LUSTER; ROUGH TO SMOOTH TEXTURE; MASSIVE. 8305' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY; SOFT TO MUSHY; COMMONLY POORLY PRESERVED; SLIGHTLY PLATY CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; WITH MINOR AMOUNTS OF LOOSE CLEAR TO EPOCH 19 Forest Oil Corporation Redoubt Unit #2 TRANSLUCENT QUARTZ GRAINS; INTERBEDDED WITH THIN BLACK COALS. 8350' SAND = WHITE TO LIGHT GRAY; LOOSE CLEAR QUARTZ GRAINS; FINE TO VERY FINE GRD; WELL SORTED, ANGULAR TO SUBANGULAR; HIGH SPHERICITY; SLIGHT CALCAREOUS CEMENT COATING; NO MATRIX PRESERVED; NO FLUORESCENCE OR CUT. 8405' COAL = BLACK; MODERATELY FIRM TO SLIGHTLY HARD; PLATY TO SCALY CUTTINGS; PLANAR TO SPLINTERY FRACTURE; SLIGHTLY RESINUOUS LUSTER; ROUGH TO SMOOTH TEXTURE; MASSIVE. 8435' SANDSTONE = PREDOMINANTLY LOOSE GRAINS; TRACE AMOUNTS OF LIGHT GRAY SANDSTONE; CLAST SIZE RANGES FROM UPPER MEDIUM TO LOWER FINE GRAINED; PREDOMINANTLY CLEAR GRAINS, SOME WHITE TO LIGHT GRAY; LOW TO MODERATELY SPHERICITY; MODERATELY WELL SORTED; RARE GRAIN SUPPORTED SPECIMENS WITH CALCAREOUS CEMENT; TRACE AMOUNTS OF WHITE CLAY MATRIX MATERIAL IN SAMPLES; 10% LIGHT GRAY CHERT; NO OIL INDICATORS. 8505' COAL = BLACK; SLIGHTLY TO MODERATELY HARD; OCCASIONALLY BRITTLE; BLOCKY TO PLANAR FRACTURE; PLATY TO SCALY CUTTINGS; DULL TO SLIGHTLY RESINUOUS LUSTER; ROUGH TO SMOOTH TEXTURE. 8535' SANDSTONE = PREDOMINANTLY LOOSE GRAINS; ABUNDANT CLEAR TO LIGHT GRAY GRAINS; UPPER MEDIUM TO LOWER FINE GRAINED; MODERATELY SORTED; LOW TO MODERATELY SPHERICITY; DOMINANTLY SUBANGULAR TO SUBANGULAR; RARE GRAIN SUPPORTED SPECIMENS WITH CALCITE CEMENT; SOME WHITE CLAY AND ASH FILL; MINOR AMOUNTS OF CHERT; 90% QUARTZ; NO OIL INDICATORS. 8580' COAL = GREENISH-BLACK TO BLACK; DENSE TO BRITTLE; PLANAR TO CONCHOIDIAL FRACTURE; MASSIVE TO PLATY CUTTING HABIT; METALLIC TO VITREOUS OCCASIONALLY WAXY LUSTER; SMOOTH TO CLAYEY TEXTURE; THIN BEDDING STRUCTURE. 8615' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; SOFT TO MUSHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; COMMON BLACK CARBONACEOUS MATERIAL PRESENT. 8650' SAND = MEDIUM LIGHT GRAY TO LIGHT GRAY; LOWER MEDIUM TO UPPER FINE OCCASIONALLY UPPER COARSE TO UPPER VERY COARSE; POOR TO FAIR SORTING; ANGULAR TO SUBANGULAR; LOW TO MODERATE SPHERICITY; 60% CLEAR TO TRANSLUCENT QUARTZ, 40% CHERT AND LITHIC FRAGMENTS; UNCONSOLIDATED; GRAIN AND MATRIX SUPPORTED; NO OIL INDICATORS PRESENT. [::1 EPOCH 20 Forest Oil Corporation Redoubt Unit #2 8700' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; SOFT TO MUSHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; MASSIVE BEDDING STRUCTURE; VERY HYDROPHILIC. 8735' SAND = LIGHT GRAY TO MEDIUM LIGHT GRAY, STRONG SALT AND PEPPER APPEARANCE; LOWER MEDIUM TO UPPER FINE; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; DOMINATLY CLEAR TO VERY LIGHT GRAY QUARTZ WITH CHERT AND LITHIC FRAGMENTS PRESENT; GRAIN SUPPORTED; NO OIL INDICATORS PRESENT. 8780' SANDSTONE/CONGLOMERATE = VERY LIGHT GRAY OVERALL; CLEAR TO WHITE GRAINS; BROKEN COARSE ANGULAR FRAGMENTS; DOMINANTLY UPPER MEDIUM TO FINE GRAINED; ANGULAR TO SUBROUNDED; POOR TO MODERATELY SORTING; QUARTZ 70%; CHERT 20%; 10% IGN/META; RARE GRAIN SUPPORTED; ESTIMATED GOOD POROSITY AND PERMEABILITY; NO OIL INDICATORS PRESENT. 8825' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; VERY SOFT; MUSHY-POORLY PRESERVED IN SAMPLES-READILY DISSOLVES IN MUD SYSTEM; MASSIVE TO SLIGHTLY PLATY CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER CLAYEY TO SILTY TEXTURE; OCCASIONALLY VERY SILTY GRADING TO TUFFACEOUS SILSTSTONE; INTERBEDDED WITH THIN COALS. NOTE: CARBIDE LAG AT 8881' - 8033 STROKES: 1% WASHOUT 8905' COAL = BLACK; MODERATELY HARD; BRITTLE IN PART; BLOCKY TO PLATY CUTTINGS; VITREOUS LUSTER; SMOOTH TEXTURE; PLANAR TO BLOCKY FRACTURE; SOME BLEEDING GAS; PLANT IMPRINTS. 8935' SAND = WHITE TO LIGHT GRAY OVERALL WITH OCCASIONAL ORANGE AND RED GRAIN; MEDIUM LOWER TO MEDIUM UPPER GRAIN SIZE; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; OCCASIONALLY FROSTED GRN; CLAY MATRIX; SLIGHTLY CALCAREOUS CEMENT; NO CUT NO FLUORESCENCE. 8975' SANDSTONE = DOMINANTLY LOOSE GRAINS; CLAST SIZE RANGES FROM UPPER MEDIUM TO LOWER FINE GRAINED; TRACE AMOUNTS OF LOWER COARSE GRAINS; ANGULAR TO SUBANGULAR; LOW TO MODERATELY SPHERICITY; FAIR SORTING; PROBABLY CLAY MATRIX; NO OIL INDICATORS. NOTE: REACH CASING POINT AT 9029', (7548.8' TVD) AT 10:30AM ON 3/15/2001. CASING SHOE AT 9011'. [::1 EPOCH 21 Forest Oil Corporation Redoubt Unit #2 DRILL TO 9049' WITH OIL BASE MUD SYSTEM AND TEST CASING. 9065' TUFFACEOUS SlLTSTONE = LIGHT TO MEDIUM GRAY; SLIGHTLY PLATY; IRREGULAR FRACTURE; FIRM TO SLIGHTLY HARD; EARTHY LUSTER; SILTY TEXTURE; VARIABLE AMOUNTS OF ASH; GRADES TO VERY FINE GRAINED SANDSTONE. 9095' TUFF = BLUISH WHITE TO WHITE, OCCASIONALLY VERY PALE GREEN; VERY SOFT TO MUSHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; GREASY TO WAXY LUSTER; CLAYEY TO SILTY TEXTURE. 9125' TUFFACEOUS SILTSTONE = MEDIUM GRAY TO DARK GRAY; CRUMBLY TO CRUNCHY; IRREGULAR FRACTURE; MASSIVE TO CURVED CUTTING HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; COMMON CARBONACEOUS LAMINATION. 9160' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; MUSHY TO PASTY CONSISTENCY; SOFT TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE CUTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE BEDDING STRUCTURE. 9200' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE; IRREGULAR TO PLANAR FRACTURE; MASSIVE CUTTINGS HABIT; METALLIC TO VITREOUS LUSTER; CLAYEY TO SILTY TEXTURE; THIN BEDDING STRUCTURE. 9230' TUFFACEOUS SlLTSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; CRUMBLY TO CRUCHY TENACITY, EASILY SCORED; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; WAXY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; COMMON CARBONACEOUS LAMINATION. 9270' SAND = LIGHT GRAY TO MEDIUM LIGHT GRAY; LOWER COARSE TO UPPER MEDIUM, OCCASIONALLY VERY COARSE TO PEBBLE; FAIR SORTING; SUBANGULAR TO SUBROUNDED; MODERATE TO HIGH SPHERICITY; 50% CLEAR TO TRANSLUCENT QUARTZ, 40% WHITE TO LIGHT GRAY CHERT, 10% LITHIC FRAGMENTS RANGING FROM LIGHT RED TO PALE GREEN; UNCONSOLIDATED; MATRIX AND GRAIN SUPPORTED; NO VISIBLE OIL INDICATORS. 9325' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; MUSHY TO PASTY CONSISTENSY; SOFT TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; WAXY TO DULL LUSTER; CLAYEY TO SILTY TEXTURE; COMMON CARBONACEOUS LAMINATION. EPOCH 22 Forest Oil Corporation Redoubt Unit #2 9365' SAND/CONGLOMERATE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; UPPER COARSE TO LOWER COARSE, OCCASIONALLY VERY COARSE TO PEBBLE; POORLY SORTED; ANGULAR TO SUBANGULAR WITH HIGH AMOUNTS OF BIT FRACTURED GRAINS; LOW TO MODERATE SHPREIClTY; MATRIX AND GRAIN SUPPORTED; UNCONSOLIDATED; NO VISIBLE OIL INDICATORS. 9415' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE; PLATY CUTTINGS HABIT; VITREOUS TO WAXY LUSTER; CLAYEY TO SILTY TEXTURE; THIN BEDDING STRUCTURE. 9445' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; MUSHY TO PASTY, OCCASIONALLY GELATINOUS; SOFT TO MUSHY TENACITY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE BEDDING STRUCTURE. 9485' TUFFACEOUS SlLTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; CRUMBLY TO CRUNCHY TENACITY; IRREGULAR FRACTURE; PDC GROOVED CUTTING HABIT; WAXY TO DULL LUSTER; SILTY TO GRITY TEXTURE; MASSIVE BEDDING STRUCTURE. 9520' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE TENACITY; IRREGULAR TO PLANAR FRACTURE; MASSIVE CUTTINGS HABIT; VITREOUS TO WAXY LUSTER; SILTY TO MATTE TEXTURE; THIN BEDDING STRUCTURE. 9550' TUUFACEOUS SlLTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; CRUMBLY TO CRUNCHY; IRREGULAR FRACTURE; PDC GROOVED CUTTINGS HABIT; WAXY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; MASSIVE BEDDING STRUCTURE; COMMON CARBONACEOUS MATERIAL PRESENT THROUGHOUT THE SAMPLE. 9595' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE TENACITY; IRREGULAR FRACTURE; MASSIVE TO PLATY CUTTINGS HABIT; VITREOUS TO WAXY LUSTER; CLAYEY TO MATTE TEXTURE; THIN BEDDING STUCTURE. 9630' SANDSTONE = VERY LIGHT GRAY; FIRM TO FRIABLE; DOMINANTLY UPPER TO LOWER MEDIUM GRAINED; MINOR AMOUNTS OF FINE GRAINED LOOSE QUARTZ; FAIR TO WELL SORTED; ANGULAR TO SUBANGULAR; LOW TO MODERATELY SPHERICITY; GRAIN SUPPORTED; WHITE ASH AND CLAY FILLING; QUARTZ 80%; 20% CHERT AND FELDSPAR; TRACE AMOUNTS OF GREEN GRAINS; MINOR AMOUNTS OF [:l EPOCH 23 Forest Oil Corporation Redoubt Unit #2 CALCITE IN MATRIX; SOME SCATTERED BLACK CARBONACEOUS MATERIAL; NO OIL INDICATORS. 9690' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; SOFT TO FIRM; IRREGULAR FRACTURE; MASSIVE TO SLIGHTLY PLATY CUTTINGS; DULL EARTHY LUSTER; CLAYEY TEXTURE; OCCASIONALLY MODERATELY SILTY; OCCASIONAL SCATTERED BLACK CARBONACEOUS MATERIAL; OCCASIONAL INTERBD WITH COAL. 9730' TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT TO MUSHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS; EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; OCCASIONAL MODERATELY SILTY; OCCASIONAL BLACK CARBONACEOUS LAMINATIONS. 9760' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY; SOFT TO FIRM; OCCASIONALLY MUSHY; IRREGULAR FRACTURE; MASSIVE TO SLIGHTLY PLATY CUTTING; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; VARIABLE AMOUNTS OF SILT; OCCASIONALLY CARBONACEOUS. 9795' SANDSTONE = PREDOMINANTLY LOOSE GRAINS; LIGHT GRAY; SLIGHTLY FRIABLE; UPPER MEDIUM TO FINE GRAINED; MODERATELY WELL SORTED; ANGULAR TO SUBANGULAR; LOW TO MODERATELY SPHERICITY; GRAIN SUPPORTED WITH ABUNDANT CLAY FILL; 70% QUARTZ; 30% LITHIC FRAGMENTS INCLUDING CHERT, FELDSPAR AND UNDIFFERENTIATED GREEN GRAINS; NO OIL INDICATORS. 9840' COAL = BLACK TO GRAY BLACK; DENSE TO BRITTLE TENACITY; CONCHOIDAL TO IRREGULAR FRACTURE; PLATY TO TABULAR CUTTING HABIT; VITREOUS TO DULL LUSTER; MATTE TEXTURE; THIN BDD STRUCTURE 9875' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO DARK REDDISH GRAY; LUMPY CONSISTANCY; SOFT TO CRUMBLY TENACITY; BLOCKY TO EARTHY FRACTURE; MASSIVE HABIT; DULL TO EARTHY LUSTER; CLAYEY TEXTURE; THIN LAMINAE. 9930' TUFFACEOUS SILTSTONE = LIGHT TO MEDIUM LIGHT GRAY; FIRM TO SOFT; IRREGULAR FRACTURE; SLIGHTLY PLATY CUTTINGS; SLIGHTLY VITREOUS LUSTER; SILTY TEXTURE; CLAY/ASH MATRIX; NON CALC; OCCASIONALLY SANDY/GRADING TO VERY FINE GRAINED SS. 9965' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY WITH LIGHT GRAY SECONDARY HUE; MUSHY CONSISTENCY; SOFT TO MODERATELY FIRM; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT, OCCASIONALLY PDC GROOVED; DULL TO EARTHY LUSTER; EPOCH 24 Forest Oil Corporation Redoubt Unit #2 CLAYEY TO SILTY TEXTURE; MASSIVE BEDDING STRUCTURE WITH CARBONACEOUS MATERIAL PRESENT. NOTE: WIPER TRIP @10006' 10005' SAND/SANDSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; UPPER COARSE TO UPPER MEDIUM WITH GRAINS RANGING FROM VERY COARSE TO PEBBLE SIZE; ANGULAR TO SUBANGULAR WITH HIGH AMOUNTS OF BIT FRACTURED GRAINS; LOW TO MODERATE SPHERICITY; UNCONSOLIDATED; MATRIX / GRAIN SUPPORTED; NO VISIBLE OIL INDICATORS. 10075' TUFFACEOUS SlLTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; CRUMBLY TENACITY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; WAXY TO DULL LUSTER WITH PDC GROOVED BEING VITREOUS TO METALLIC; SILTY TO GRITY TEXTURE; BLACK CARBONACEOUS MATERIAL PRESENT THROUGHOUT THE SAMPLE. 10125' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE; IRREGULAR TO PLANAR FRACTURE OCCASIONALLY CONCHOIDAL; MASSIVE TO PLATY CUTTINGS HABIT; VITREOUS LUSTER; SILTY TO MATTE TEXTURE; THIN BEDDING STRUCTURE; NO VISIBLE GAS BLEEDING. 10160' SANDSTONE/CONGLOMERATE = VERY LIGHT GRAY TO MEDIUM LIGHT GRAY; GRAINS RANGE IN COLOR FROM WHITE TO CLEAR TO LIGHT GRAY TO GREEN; CLAST SIZE FROM BROKEN PEBBLE SIZE TO UPPER FINE GRAINED; SUBANGULAR TO SUBANGULAR; POORLY SORTED; LOW TO MODERATELY SPHERICITY; FIRM TO SLIGHTLY FRIABLE; MATRIX TO GRAIN SUPPORTED; WHITE ASH AND CLAY FILL; MINOR AMOUNTS OF CALCITE CEMENT; OCCASIONALLY SOME CARBONACEOUS FRAGMENTS; NO DISCERNIBLE CHANGE IN OIL-MUD BACKGROUD FLUORESCENCE IN SAMPLES. 10225' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; SOFT TO FIRM; OCCASIONALLY MUSHY TO PASTY; OCCASIONALLY CRUMBLY WHEN SILTY; IRREGULAR TO OCCASIONALLY BLOCKY FRACTURE; MASSIVE TO SLIGHTLY PLATY CUTTINGS; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; OCCASIONALLY VERY SILTY; OCCASIONALLY INTERBEDDED WITH THIN BLACK COAL. 10270' TUFFACEOUS SlLTSTONE = MEDIUM LIGHT GRAY; SLIGHTLY TO MODERATELY FIRM; IRREGULAR TO BLOCKY FRACTURE; MASSIVE TO SLIGHTLY PLATY CUTTINGS; GREASY TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; VARIABLE AMOUNTS OF ASH; OCCASIONALLY MODERATELY CARBONACEOUS. EPOCH 25 Forest Oil Corporation Redoubt Unit #2 10305' COAL = BLACK; FIRM TO MODERATELY HARD; PLATY TO BLOCKY CUTTINGS; PLANAR TO BLOCKY FRACTURE; SLIGHTLY VITREOUS LUSTER; ROUGH TEXTURE; INTERBEDDED WITH CLAYSTONE. 10330' TUFFACEOUS SlLTSTONEISANDSTONE = VERY LIGHT GRAY; MASSIVE TO SLIGHTLY NODULAR CUTTINGS; CRUMBLY TENACITY; IRREGULAR FRACTURE; DULL LUSTER; GRITTY TEXTURE; SILT TO VERY FINE CLEAR QUARTZ IN GRAY CLAY MATRIX; MATRIX SUPPORTED; INTERBEDDED WITH THIN COALS. 10370' COAL = BLACK; FIRM TO SLIGHTLY HARD; OCCASIONALLY BRITTLE; BLOCKY TO SPLINTERY FRACTURE; SLIGHTLY PLATY CUTTINGS; SLIGHTLY RESINOUS LUSTER; ROUGH TO SMOOTH TEXTURE. 10395' SANDSTONE = WHITE TO LIGHT TAN AND GRAY; FINE TO MEDIUM WITH OCCASIONALLY PEBBLE GRAIN SIZE; POOR TO FAIR SORTING; ANGULAR TO SUBANGULAR; LOW TO MODERATE SPHERICITY; CLAY AND ASH MATRIX; MATRIX SUPPORTED; OIL INDICATORS OBSCURED BY OIL BASE MUD. 10435' TUFFACEOUS SlLTSTONEI SANDSTONE = WHITE TO LIGHT GRAY; FRIABLE TO CRUMBLY; CLAST SIZE RANGES FROM FINE TO SILT SIZE PARTICLES; WELL SORTED; ANGULAR TO SUBANGULAR; ABUNDANT ASH AND CLAY MATRIX; MATRIX SUPPORTED; NO OIL INDICATORS. 10475' TUFFACEOUS CLAYSTONE = LIGHT TAN TO DARK TAN AND GRAY; LUMPY CONSISTANCY; CRUMBLY TENACITY; NO OBSERVED FRACTURES; PLATY HABIT WITH A EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; THIN BEDDED; POSSIBLY VARVED; OCCASIONAL CARBONACEOUS LENSES. 10510' COAL/CARBONACEOUS SHALE = BLACK TO BROWN; FIRM TO HARD; ALTERNATING THIN BEDS OF COAL AND CARBONACEOUS SHALE AND CLAYSTONE. NOTE: WIPER TRIP AT 10548'. 10565' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE OCCASIONALLY CRUMBLY; IRREGULAR TO PLANAR FRACTURE; MASSIVE TO FLAKY CUTTINGS HABIT; VITREOUS TO GREASY LUSTER; SILTY TO MATTE TEXTURE; THIN BEDDING STRUCTURE. 10600' TUFFACEOUS SlLTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY WITH BROWNISH BLACK SECONDARY HUE; CRUMBLY TO CRUNCHY OCCASIONALLY DENSE; IRREGULAR FRACTURE; MASSIVE TO [::1 EPOCH 26 i~ Forest Oil Corporation Redoubt Unit #2 PDC GROOVED CUTTINGS HABIT; DULL TO EARTHY LUSTER WITH POLISHED PDC MARKINGS; CLAYEY TO SILTY TEXTURE; MASSIVE BEDDING STRUCTURE; CARBONACEOUS MATERIAL PRESENT THROUGHOUT THE SAMPLE. 10655' TUFFACEOUS SlLTSTONE = PREDOMINANTLY LIGHT GRAY; SOME MEDIUM GRAY; OCCASIONALLY CARBONACEOUS WITH BROWNISH HUE; MASSIVE CUTTING HABIT; IRREGULAR FRACTURE; DULL EARTHY LUSTER; GRITTY TO SILTY TEXTURE; VARIABLE AMOUNTS OF WHITE ASH IN MATRIX; OCCASIONALLY MODERATELY SANDY WITH LOOSE CLEAR TO TRANSLUCENT QUARTZ GRAINS; GRADING TO FINE GRAINED MATRIX SUPPORTED SANDSTONE; ABUNDANT LOOSE CARBONACEOUS MATERIAL; CARBONACEOUS STREAKS AND LAMINATIONS. 10715' TUFFACEOUS SlLTSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; SOFT TO FIRM; MASSIVE CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY TO SLIGHTLY WAXY LUSTER; GRITTY TO SILTY TEXTURE; OCCASIONALLY GRADING TO SANDSTONE; SCATTERED CARBONACEOUS MATERIAL. 10750' COAL = BLACK; SOME BROWNISH BLACK; FIRM TO MODERATELY HARD; BRITTLE; SPLINTERY TO PLATY CUTTINGS; BLOCKY TO PLANAR FRACTURE; WAXY LUSTER; SMOOTH TO MATTE TEXTURE; LIGNITIC TO SUBBITUMINOUS. 10780' TUFFACEOUS SILTSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; OCCASIONALLY CARBONACEOUS BROWN; FIRM TO MODERATELY HARD; MASSIVE CUTTINGS; IRREGULAR FRACTURE; DULL TO SLIGHTLY WAXY LUSTER; GRITTY TO SILTY TEXTURE. 10810' COAL = BLACK TO DULL BLACK; FIRM TO MODERATELY HARD; HACKLY FRACTURE; GREASY TO RESINOUS LUSTER; SMOOTH TO GRITTY TEXTURE; SUBBITUMINOUS TO PEATY. 10840' TUFFACEOUS SILTSTONE = LIGHT GRAY TO LIGHT TANISH GRAY WITH ALTERNATING STREAKS OF DARK CARBONACEOUS MATERIAL; IRREGULAR FRACTURE; TABULAR TO PLATY HABIT; GENERALLY EARTHY LUSTER WITH THIN STREAKS OF VITREOUS LUSTER; MOSTLY CLAYEY TEXTURE; THIN BEDDED. 10880' COAL = BLACK TO SHINY BLACK; FIRM TO HARD; CONCHOIDAL FRACTURE; PLATY FRACTURE; RESINOUS LUSTER; SMOOTH TEXTURE; INTERBEDDED WITH THIN TUFFACEOUS CLAYSTONE LENS. 10910' SANDSTONE = LIGHT GRAY; SLIGHTLY FRIABLE; LOWER MEDIUM GRAINED TO FINE GRAINED; MODERATELY WELL SORTED; ANGULAR TO EPOCH 27 Forest Oil Corporation Redoubt Unit #2 SUBANGULAR; MODERATELY SPHERICITY; VERY CLAYEY WITH CLAY SUPPORTED MATRIX; FeO GRAINS; OCCASIONALLY MOTTLED; THIN CLAY LAMINATIONS; NO OIL INDICATORS. 10950' CONGLOMERATIC SANDSTONE = LIGHT GRAY TO OFFWHITE; VERY HARD; CLAST SIZE FROM VERY COARSE TO FINE GRAINED; POORLY SORTED; ANGULAR TO SUBROUNDED; LOW TO MODERATELY SPHERICITY; LOOSE GREEN AND FeO COATED GRAINED; GRAIN SUPPORTED; SILICACEMENT; MINOR AMOUNTS OF CALCITE FILL; ABUNDANT WHITE ASH AND CLAY PROBABLY MATRIX MATERIAL IN SAMPLES; NO OIL INDICATORS. NOTE: WIPER TRIP AT 11001' 11030' TUFFACEOUS SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY WITH GRAYISH BROWN SECONDARY HUE; SOFT TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; WAXY TO DULL OCCASIONALLY EARTHY LUSTER; SILTY TO GRITTY TEXTURE; BLACK TO REDDISH BLACK CARBONACEOUS MATERIAL PRESENT. 11075' TUFF = WHITE; VERY LIGHT GRAY; VERY SOFT; CRUMBLY; OCCASIONALLY MUSHY TO PASTY; MASSIVE TO SLIGHTLY NODULAR SHAPE CUTTINGS; IRREGULAR FRACTURE; WAXY TO DULL LUSTER; SILTY TEXTURE; GRADING TO TUFFACEOUS SILTSTONE. 11110' SANDSTONE/CONGLOMERATE = PREDOMINANTLY LOOSE GRAINS; LIGHT GRAY; INDIV. GRAINS VARY FROM CLEAR TO WHITE WITH MINOR AMOUNTS OF LIGHT GRAY TO LIGHT RED; PRESERVED SPECIMENS MODERATELY HARD; UPPER COARSE TO FINE GRAINED; POORLY SORTED; ANGULAR TO SUBANGULAR; MATRIX SUPPORTED; WHITE TO LIGHT GRAY ASH AND CLAY MATRIX; NO OIL INDICATORS. 11160' COAL = BLACK; MODERATELY HARD; PLANAR TO BLOCKY FRACTURE; PLATY TO FLAKY CUTTINGS; SLIGHTLY RESINUOUS TO VITREOUS LUSTER; SMOOTH TO ROUGH TEXTURE; GRADING TO CARBONACEOUS SHALE; THICKLY BEDDED. 11210' CONGLOMERATIC SANDSTONE = PREDOMINANTLY LOOSE GRAINS; CLAST SIZE FROM BROKEN PEBBLE TO FINE GRAINED; WHITE, LIGHT GREEN, OCCASIONAL FeO STAIN ON GRAINS; POORLY SORTED; SUBANGULAR TO SUBANGULAR; RARE MATRIX SUPPORTED; SPECIMENS W/ASH/CLAY MATRIX; ASSOC W/COAL SECTION; OCCASIONAL PARTICLES EXHIBIT THIN COALY STREAKS; NO OIL INDICATORS. NOTE: TRIP OUT FOR NEW BIT AT 11249'. [::l EPOCH 28 Forest Oil Corporation Redoubt Unit #2 11265' SANDSTONE= WHITE TO VERY LIGHT GRAY; SOFT TO FRIABLE; UPPER MEDIUM TO LOWER FINE GRAINED; MODERATELY WELL SORTED; ANGULAR TO SUBANGULAR; LOW TO MODERATELY SPHERICITY; MATRIX SUPPORTED; WHITE ASH MATRIX; ABUNDANT WHITE ASH MATRIX MATERIAL IN SAMPLES; MINOR AMOUNTS OF CHERT, BLACK IGN/MET LITHIC FRAGMENTS; NO OIL INDICATORS. 11315' SANDSTONE = LIGHT GRAY TO OFFWHITE; FRIABLE TO SOFT; LOWER MEDIUM TO LOWER FINE GRAINED; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; MODERATELY SPHERICITY; MATRIX TO GRAIN SUPPORTED; ABUNDANT WHITE ASH/SILT MATRIX MATERIAL; MINOR AMOUNTS OF CHERT; OCCASIONALLY VERY CARBONACEOUS; GRADING TO TUFFACEOUS SILTSTONE; NO OIL INDICATORS. 11365' COAL = BLACK; MODERATELY HARD; PLATY TO SLIGHTLY SPLINTERY CUTTING; BLOCKY FRACTURE; SLIGHTLY VITREOUS LUSTER; SMOOTH TEXTURE; INTERBEDDED WITH TUFFACEOUS CLAYSTONE. 11390' TUFFACEOUS SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY; MODERATELY INDURATED; MASSIVE CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; GRITTY TO SILTY TEXTURE; SILT TO VERY FINE QUARTZ GRAINS IN WHITE ASH AND CLAY MATRIX; OCCASIONALLY WITH CARBONACEOUS LAMINATIONS. 11430' COAL = BLACK; MODERATELY HARD; OCCASIONALLY BRITTLE; BLOCKY TO CONCHOIDAL FRACTURE; PLATY TO ELONGATED CUTTINGS; SLIGHTLY VITREOUS LUSTER; SMOOTH TO ROUGH TEXTURE; GRADES TO CARBONACEOUS SHALE. 11460' TUFFACEOUS SlLTSTONE = LIGHT BROWN TO GRAYISH BROWN; SLIGHTLY FIRM TO VERY FIRM; CRUMBLY IN PART; IRREGULAR TO SUBBLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTING HABIT; EARTHY LUSTER; SILTY TO GRITTY TEXTURE; OCCASIONAL SMALL PEBBLE GRAINS; BECOMING INTERBEDDED COAL, CLAY, AND SILTSTONE; CLAYS ARE HIGHLY SOLUBLE. 11515' CONGLOMERATE/SAND = WHITE TO LIGHT GRAY; POORLY INDURATED; MEDIUM TO UPPER COARSE; POORLY SORTED; ASH / CLAY MATRIX; NO OIL INDICATORS. 11540' TUFFACEOUS SlLTSTONE I SAND = LIGHT BROWN TO GRAYISH BROWN; FAIRLY WELL INDURATED; FIRM TO STIFF CONSISTENCY; DENSE TO CRUMBLY TENACITY; HACKY FRACTURE; TABULAR CUTTINGS HABIT; SLIGHTLY EARTHY LUSTER; GRANULAR TO SUCROSIC TEXTURE; CARBONACEOUS; GRADING TO SANDSTONE; INTERBEDDED WITH COAL. [:l EPOCH 29 Forest Oil Corporation Redoubt Unit #2 11615' SAND I CONGLOMERATE = MEDIUM GRAY TO BROWNISH GRAY WITH MODERATE BROWN SECONDARY HUE; UPPER MEDIUM TO LOWER COARSE OCCASIONALLY RANGING TO PEBBLE SIZE GRAINS; POORLY SORTED; SUBANGULAR TO SUBROUDED WITH OCCASIONAL BIT FRACTURED GRAINS; LOW TO MODERATE SPHERICITY; UNCONSOILIDATED; ASH AND CLAY MATRIX SUPPORTED; BLACK TO BROWNISH BLACK CARBONACEOUS MATERIAL PRESENT THROUGHOUT SAMPLE; NO OIL INDICATORS PRESENT. 11680' TUFFACEOUS SILTSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY WITH BROWNISH GRAY SECONDARY HUE; SOFT TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; WAXY TO DULL LUSTER; CLAYEY TO SILTY TEXTURE; CABONACEOUS LAMINATIONS PRESENT THROUGHOUT SAMPLE. 11725' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE TENACITY; IRREGULAT TO PLANAR FRACTURE; MASSIVE CUTTINGS HABIT; VITREOUS TO GREASY LUSTER; SILTY TO MATTE TEXTURE; THIN BEDDING STRUCTURE. 11755' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY WITH BROWNISH GRAY SECONDARY HUE; CLUMPY TO MUSHY CONSISTENCY; SOFT TO CRUMBLY TENACITY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE BEDDING STRUCTURE; CARBONACEOUS MATERIAL PRESENT THROUGHOUT SAMPLE. 11805' TUFFACEOUS SlLTSTONE = MEDIUM GRAY TO LIGHT BROWNISH GRAY WITH PALE BROWN SECONDARY HUE; CRUMBLY TO CRUNCHY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; WAXY TO DULL LUSTER WITH PDC GROOVED FRAGMENTS HAVING A METALLIC LUSTER; SILTY TO GRITTY TEXTURE; MASSIVE BEDDING STRUCTURE; BLACK TO BRNISH BLACK CARBONACEOUS MATERIAL PRESENT THROUGHOUT THE SAMPLE. 11865' COAL = BLACK TO BROWNISH BLACK; BRITTLE TO CRUMBLY TENACITY; IRREGULAR TO PLANAR FRACTURE; MASSIVE CUTTINGS HABIT; VITREOUS TO WAXY LUSTER; SILTY TO MATTE TEXTURE; THIN BEDDING STRUCTURE. 11900' TUFFACEOUS SlLTSTONE = MEDIUM GRAY TO LIGHT GRAY; MASSIVE CUTTINGS; IRREGULAR FRACTURE; FIRM; OCCASIONALLY SOFT; DULL EARTHY TO SLIGHTLY WAXY LUSTER; CRUMBLY TO FRIABLE; GRITTY TO SILTY LUSTER; VARIABLE AMOUNTS OF WHITE ASH; VARIABLE AMOUNTS OF CARBONACEOUS MATERIAL; OCCASIONAL THIN COALY LAMINATIONS. EPOCH 3o Forest Oil Corporation Redoubt Unit #2 11940' COAL = BLACK; MODERATELY HARD; PLATY TO SCALY CUTTINGS; PLANAR TO BLOCKY FRACTURE; SLIGHTLY RESINUOUS TO SLIGHTLY VITREOUS LUSTER; ROUGH TO SMOOTH TEXTURE. NOTE: SHORT TRIP AT 12016'. 11995' TUFFACEOUS SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY; SOME BROWNISH GRAY; SOFT TO CRUMBLY; MASSIVE CUTTINGS; IRREGULAR FRACTURE; GRITTY TEXTURE; DULL TEXTURE; OCCASIONAL THIN ASHEY LAMINATIONS CARBONACEOUS IN PART. 12030' COAL = BLACK; FIRM TO SLIGHTLY SOFT; CRUMBLY; WEDGELIKE TO FLAKY CUTTINGS; SPLINTERY FRACTURE; SLIGHTLY RESINUOUS LUSTER; SMOOTH TO MATTE TEXTURE; SUBBITUMINOUS. 12055' TUFFACEOUS SILTSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY WITH BROWNISH GRAY SECONDARY HUE; MODERATELY FIRM TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO PDC GROOVED CUTTINGS HABIT; WAXY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDED WITH BLACK TO BROWNISH BLACK CARBONACOEUS MATERIAL AND TUFFACEOUS CLAYSTONE. 12105' COAL = BLACK TO GRAYISH BLACK WITH BROWNISH BLACK SECONDARY HUE; BRITTLE TO MODERATLY FIRM TEAClTY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; VITREOUS LUSTER; SILTY TO MATTE TEXTURE; THIN BEDDING STRUCTURE; NO VISIBLE GAS BLEEDING. 12145' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; MODERATELY COHESIVE; MODERATELY ADHESIVE; MUSHY CONSISTENCY; SOFT TO CRUMBLY TENACITY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; INTERBEDED WITH BLACK CARBONACEOUS MATERIAL. 12190' SAND = MEDIUM DARK GRAY TO BROWNISH GRAY; UPPER MEDIUM TO LOWER COARSE; FAIR TO WELL SORTED; SUBROUNDED; MODERATE SPHERICITY; MATRIX SUPPORTED; CARBONACEOUS MATERIAL PRESENT THROUGHOUT SAMPLE; NO OIL INDICATORS PRESENT. NOTE: TRIP OUT FOR NEW BIT AT 12234'. 12260' CONGLOMERATE/SILTSTONE = LIGHT BROWNISH GRAY; MOTTLED IN PART; CLAST SIZE RANGES FROM UPPER COARSE TO SILT SIZE GRAINS; GRAINS ARE PREDOMINANTLY SILT SIZED; GRADING TO SILTSTONE; LOW SPHERICITY; MATRIX SUPPORTED; WHITE ASH TO SILT EPOCH Forest Oil Corporation Redoubt Unit #2 MATRIX; VERY CARBONACEOUS WITH SCATTERED BLACK MATERIAL IN MATRIX; NO OIL INDICATORS. 12325' CONGLOMERITIC SAND = GRAYISH WHITE TO GRAY; PREDOMINANTLY FROSTED QUARTZ GRAINS WITH OCCASIONAL CLEAR AND RARE YELLOW TO ORANGE; MAJOR FACTION ARE FINE GRAIN GRADING TO COARSE IN MINOR FRACTION; FAIR TO POOR SORTING; SUBROUNDED TO SUBANGULAR; MODERATE SPHERICITY; OIL INDICATORS OBSCURED DUE TO OIL BASE MUD. 12375' CONGLOMERIC SAND/SlLTSTONE = WHITE TO LIGHT GRAY OVERALL WITH NUMEROUS SALT AND PEPPER COLORED GRAINS; COMPOSED OF QUARTZ SANDS, ROCK FRAGMENTS AND OCCASIONAL CARBONACEOUS GRANULES; FINE GRAIN MATRIX WITH INCREASING LARGE GRAIN FRACTION; VERY POOR SORTING; FINE GRAINS ARE ROUNDED TO SUBROUNDED AND LARGE GRAIN PARTICLES ARE SUBANGULAR TO ANGULAR; NO OIL INDICATORS PRESENT. 12435' TUFFACEOUS SlLTSTONE = LIGHT GRAY TO TAN OVERALL WITH OCCASIONALLY RED TAN AND GRAY ORANGE CLASTS; DENSE AND HARD; BLOCKY FRACTURE; MASSIVE HABIT EARTHY TO DULL LUSTER; GRITTY TEXTURE; NO VISIBLE BEDDING OR STRUCTURAL INDICATORS; OCCASIONAL COAL AND CARBONACEOUS SHALE. 12480' TUFFACEOUS CLAYSTONE = LIGHT GRAY; FIRM TO MODERATELY HARD; MASSIVE CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; SILTY TEXTURE; SILTY IN PART GRADING TO SILTSTONE. 12510' SANDSTONE = LIGHT GRAY TO TANNISH WHITE; SOFT AND FRIABLE; UPPER MEDIUM TO FINE GRAIN; FAIR SORTING; ANGULAR TO SUBANGULAR; ASH AND CLAY MATRIX SUPPORTED; VERY COALY WITH ABUNDANT COAL LAMINATIONS; NO OIL INDICATORS. 12550' TUFFACEOUS SlLTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY WITH BROWNISH GRAY SECONDARY HUE; DENSE TO CRUMBLY TENACITY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; WAXY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; THIN CARBONACEOUS LAMINATIONS PRESENT THROUGHOUT THE SAMPLE. 12595' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE TENACITY; IRREGULAR TO BLOCKY FRACTURE; MASSIVE TO PLATY CUTTINGS HABIT; VITREOUS TO GREASY LUSTER; SMOOTH TO MATTE TEXTURE; THIN BEDDING STRUCTURE; NO VISIBLE GAS BLEEDING. 12630' SAND I SANDSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY WITH VERY LIGHT GRAY SECONDARY HUE; LOWER COARSE TO UPPER FINE; FAIR SORTING; SUBANGULAR TO SUBROUNDED; MODERATE TO EPOCH 32 Forest Oil Corporation Redoubt Unit #2 HIGH SPHERICITY; EASILY FRIABLE TO FRIABLE; MATRIX / GRAIN SUPPORTED; CARBONACOEUS MATERIAL PRESENT THROUGHOUT THE SAMPLE; NO OIL INDICATORS PRESENT. 12680' TUFFACEOUS SlLTSTONE = MEDIUM DARK GRAY TO DARK GRAY; CRUMBLY TENACITY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; WAXY TO DULL OCCASIONALLY SPARKLING LUSTER; SILTY TEXTURE; LAMINATED STRUCTURE. 12710' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE TENACITY; PLANAR TO CONCHOIDAL FRACTURE; MASSIVE TO PLATY CUTTINGS HABIT; VITREOUS TO METALLIC LUSTER; SMOOTH TO MATTE LUSTER; THIN BEDDING STRUCTURE. 12745' TUFFACEOUS CLAYSTONE = MEDIUM GRAY TO LIGHT MEDIUM GRAY; MODERATELY HARD; MASSIVE CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; SMOOTH TO SLIGHTLY SILTY TEXTURE; VARIABLE AMOUNTS OF SILT; SOME CARBONACEOUS MATERIAL; INTERBEDDED WITH THIN BLACK COALY STRINGERS. NOTE: FROM 12,100' MD, THE SECTION IS RAPIDLY BECOMING LOWER TO RU#1 TVD. 12825' COAL = BLACK; MODERATELY HARD; PLATY TO BLOCKY CUTTINGS; BLOCKY TO SPLINTERY FRACTURE; SMOOTH TO MATTE TEXTURE; SLIGHTLY VITREOUS LUSTER; NO VISIBLE BLEEDING GAS. 12870' TUFFACEOUS CLAYSTONE = LIGHT MEDIUM GRAY; MODERATELY HARD; MASSIVE TO SLIGHTLY PLATY CUTTINGS; IRREGULAR FRACTURE; SILTY TEXTURE; DULL EARTHY LUSTER; WITH SOME LIGHT GRAY SILTSTONE; ABUNDANT BLACK COALY LAMINATIONS; POOR SAMPLE QUALITY THROUGH THIS INTERVAL. 12910' TUFFACEOUS SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; CRUMBLY TO CRUNCHY TENACITY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; CARBONACEOUS LAMINATION PRESENT THROUGHOUT SAMPLE. 12950' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; SOFT TO MUSHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY LUSTER; COMMON CARBONACEOUS LAMINATION PRESENT. 12985' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE TENACITY; IRREGULAR AND CONCHOIDAL FRACTURE; MASSIVE [::l EPOCH 3 3 Forest Oil Corporation Redoubt Unit #2 CUTTINGS HABIT; VITREOUS TO GREASY LUSTER; SMOOTH TO MATTE TEXTURE; LAMINATED STRUCTURE. 13015' TUFF = MODERATE ORANGE PINK TO PALE YELLOWISH ORANGE OCCASIONALLY WHITE; VERY SOFT TO MUSHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE. 13045' COAL = BLACK; MODERATELY HARD TO DENSE; OCCASIONALLY BRITTLE; SLIGHTLY PLATY TO MASSIVE CUTTINGS; CONCHOIDAL TO BLOCKY FRACTURE; SLIGHTLY VITREOUS LUSTER; SMOOTH TO MATTE TEXTURE; NO VISIBLE BLEEDING GAS. 13075' SANDSTONEISILTSTONE = LIGHT GRAY; SOFT; FIRABLE IN PART; LOWER MEDIUM TO SILT SIZE; FAIR SORTING; ANGULAR TO SUBANGULAR; MATRIX TO GRAIN SUPPORTED; WHITE ASH/CLAY-SILT MATRIX; TRACE AMOUNTS OF LIGHT GREEN-BLACK GRAINS; OCCASIONAL MEDIUM BROWN TO BLACK CARBONACEOUS STREAKS; NO OIL INDICATORS. 13140' TUFFACEOUS SlLTSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; SOFT TO MODERATELY HARD; MASSIVE CUTTINGS; DULL LUSTER; SILTY TO GRITTY TEXTURE; VARIABLE AMOUNTS OF TUFF; OCCASIONALLY SANDY; SCATTERED TO THIN BLACK COALY LAMINATIONS. 13175' SANDSTONE/SAND = LIGHT TO MEDIUM GRAY; VERY FINE TO LOWER MEDIUM OCCASIONALLY COARSE AT BASE OF INTERVAL; POOR TO VERY POOR SORTING; ANGULAR TO SUBANULAR; WIDE RANGE OF SPHERICITY; APPROXIMATELY 30% QUARTZ, 30% ROCK FRAGMENTS, 20% CHERT, 20% FELDSPAR AND UNIDENTIFIED GRAINS; VERY SLIGHT LAMINATIONS; NO SEDIMENTARY STRUCTURES APPARENT; NO OIL INDICATORS DUE TO OIL BASE MUD. NOTE: TRIP OUT FOR NEW BIT AT 13255'. 13240' TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY; SOFT OCCASIONALLY FIRM; MUSHY TO STIFF; EARTHY FRACTURE; SUBPATCHY TO SUBNODULAR HABIT; MODERATE TO BRIGHT EARTHY LUSTER; CLAYEY TEXTURE; MASSIVE TO THICK BEDS OF UNIFORM CLAY; GENERALLY COMPOSED OF 80% CLAY, 200/0 SILT; OCCASIONAL SCATTERED COAL AT 13270'. 13280' TUFFACEOUS SlLTSTONE = MEDUIM GRAY TO MEDIUM DARK GRAY; CRUMBLY TO CRUNCHY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; CARBONACEOUS LAMINATION. [::l EPOCH 34 Forest Oil Corporation Redoubt Unit #2 13310' COAL = BLACK TO GREENISH BLACK; DENSE TO BRITTLE; PLANAR TO CONCHOIDAL FRACTURE; MASSIVE CUTTINGS HABIT; VITREOUS LUSTER; SMOOTH TO MATTE TEXTURE; THIN BEDDING STRUCTURE. 13340' TUFFACEOUS SlLTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; SOFT TO CRUMBLY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; WAXY TO DULL LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE BEDDING STRUCTURE; CARBONACEOUS MATERIAL PRESENT THROUGHOUT THE SAMPLE. 13380' COAL = BLACK TO GRAYISH BLACK; DENSE TO BRITTLE TENACITY; IRREGULAR OCCASIONALLY CHONCHOIDAL FRACTURE; MASSIVE CUTTINGS HABIT; METALLIC TO GREASY LUSTER; MATTE TEXTURE; THIN BEDDING STRUCTURE; NO VISIBLE GAS BLEEDING. 13415' SAND = LIGHT GRAY TO MEDIUM LIGHT GRAY; LOWER MEDIUM TO UPPER FINE; FAIR TO WELL SORTED; SUBANGULAR TO SUBROUNDED; MODERATE SPHERICITY; DOMINATLY QUARTZ WITH MINOR AMOUNTS OF CHERT AND LITHIC FRAGMENTS; UNCONSOLIDATED; GRAIN/MATRIX SUPPORTED. 13455' TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY AND VARIOUS HUES; SOFT OCCASIONALLY FIRM; SLIGHTLY MALLEABLE TO SLIGHTLY SECTILE; SLIGHTLY MUSHY OCCASIONALLY BECOMING STIFF; EARTHY FRACTURE; SUBNODULAR HABIT; MODERATE EARTHY LUSTER; CLAYEY TEXTURE; MASSIVE HOMOGENEOUS BEDDING COMPOSED OF 90% CLAY, 10% SILT, TRACES OF ASH. 13515' TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY; SOFT OCCASIONALLY FIRM; SLIGHTLY SECTILE; MUSHY OCCASIONALLY STIFF; EARTHY FRACTURE; SUB NODULAR HABIT; EARTHY LUSTER; CLAYEY OCCASIONAL ASHY TEXTURE; MASSIVE BEDS OF UNIFORM CLAY; GENERALLY COMPOSED OF 80% CLAY, 10% SILT 10% ASH. 13555' SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM MEDIUM UPPER TO FINE UPPER OCCASIONALLY FINE LOWER AND CONGLOMERATE COARSE LOWER; SUBROUND; MODERATE SPHERICITY; MODERATE SORTING IN MEDIUM TO FINE GRAINS; POLISH TEXTURE; NON TO VERY WEAK SILICA CEMENT; MODERATE TO ABUNDANT CLAY MATRIX; DOMINANTLY MATRIX SUPPORT; COMPOSED OF 30% QUARTZ, 70% CHERT; FAIR TO POOR ESTIMATED POROSITY AND PERMEABILITY; NO OIL INDICATORS. 13610' TUFFACEOUS SlLTSTONE = LIGHT BROWNISH GRAY TOBROWNISH GRAY OCCASIONALLY MEDIUM GRAY; POOR TO MODERATE INDURATION; SLIGHTLY SECTILE; MUSHY OCCASIONALLY STIFF; SUBBLOCKY TO SUBNODULAR HABIT; EARTHY FRACTURE; DULL [:l EPOCH 35 Forest Oil Corporation Redoubt Unit #2 EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS BEDS OF UNIFORM TUFFACEOUS SILT; COM;POSED OF 70% SILT, 20% CLAY, 10% ASH. 13660' COAL = GRAYISH BLACK; FIRM; EARTHY TO SUBRESINOUS LUSTER; SUBPLATY TO SUBHACKLY HABIT; MATTE TEXTURE. NOTE: WIPER TRIP AT 13684'. 13690' COAL = BLACK TO GRAYISH BLACK; BRITTLE TO CRUNCHY OCCASIONALLY DENSE TENACITY; IRREGULAR TO PLANAR FRACTURE; MASSIVE TO FLAKEY CUTTINGS HABIT; METALLIC TO VITREOUS LUSTER; MATTE TEXTURE; THIN BEDDING STRUCTURE; SLIGHT VISIBLE GAS BLEEDING. 13705' TUFF = WHITE TO VERY LIGHT GRAY; SOFT TENACITY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; WAXY LUSTER; CLAYEY TEXTURE. 13755' SAND = LIGHT GRAY; CLAST SIZE RANGES FROM FINE LOWER TO MEDIUM UPPER OCCASIONALLY BECOMING COARSE; SUBROUND; POORLY SORTED; MODERATELY SPHERICITY; PITTED TO IMPACTED TEXTURE; SLIGHT TO MODERATE CLAY/ASH MATRIX MAT; DOMINANTLY GRAIN SUPPORT WITH SECONDARY MATRIX SUPPORT; COMPOSED OF 30%QTZ, 60% CHERT, 10 METAMORPHIC FAIR TO POOR PORO AND PERMEABILITY; NO OIL. 13800' COAL = GRAYISH BLACK; FIRM; EARTHY TO SUBRESINOUS LUSTER; GRITTY TEXTURE; HACKLY TO BLOCKY FRACTURE; COMPOSED OF SUBBITUMINOUS TO SHALE/LIGINITIC. NOTE: TRIP FOR BIT AT 13823'. 13835' TUFFACEOUS SlLTSTONE = VERY LIGHT GRAY TO PINKISH GRAY OCCASIONALLY VERY PALE ORANGE; POORLY INDURATED; CRUMBLY; BRITTLE; EARTHY FRACTURE; SUBNODULAR HABIT; MODERATELY TO BRIGHT EARTHY LUSTER; SILTY TEXTURE; MASSIVE TO THICK BEDS OF UNIFORM SILT; COMPOSED OF 60% SILT, 20% ASH, 20% CLAY. 13875' SAND = PINKISH GRAY TO VERY PALE ORANGE; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE UPPER OCCASIONAL SCATTERED VERY FINE GRAINS AND COARSE GRAINS; SUBROUND; MODERATE SPHERICITY; MODERATE TO POORLY SORTED; GENERALLY POLISHED OCCASIONAL CHIPPED TEXTURE; NON TO VERY SLIGHT SILICA CEMENT; MODERATE TO ABUNDANT ASH AND CLAY MATRIX; DOMINANTLY MATRIX SUPPORTED; APPEARS REWORKED AND REDEPOSITED; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% EPOCH 36 Forest Oil Corporation Redoubt Unit #2 METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; POOR POROSITY AND VERY POOR PERMEABILITY; NO OIL INDICATORS. 13940' TUFF = WHITE TO VERY LIGHT GRAY OCCASIONALLY BLUISH WHITE; VERY SOFT TENACITY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; GREASY TO WAXY LUSTER; CLAYEY TEXTURE; TUFFS DESCRIBED ARE THE COMMON MATRIX MATERIAL FOUND IN SANDS OVER THE PAST 200'- 300'. 13980' COAL = BLACK TO GRAYISH BLACK OCCASIONALLY REDISH BLACK; BRI'I-I-LE TO CRUNCHY TENACITY; IRREGULAR TO PLANAR FRACTURE; MASSIVE TO FLAKY CUTTINGS HABIT; METALLIC TO VITREOUS LUSTER; MATTE TEXTURE; THIN BEDDING STRUCTURE; NO VISIBLE GAS BLEEDING. 14020' CARBONACEOUS SHALE = BROWNISH BLACK TO REDISH BLACK; CRUMBLY TENACI-rY; IRREGULAR FRACTURE; MASSIVE TO FLAKY CUTTINGS HABIT; WAXY TO DULL LUSTER; MATTE TO SILTY TEXTURE; THIN BEDDING STRUCTURE. 14055' SAND = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY; UPPER FINE TO LOWER FINE OCCASIONALLY UPPER MEDIUM; FAIR TO WELL SORTED; SUBROUNDED; MODERATE TO HIGH SPHERICITY; 30% QUARTZ, 70% CHERT, AND MINOR AMOUNTS OF METAMORPHIC AND LITHIC FRAGMENTS; ASH/CLAY MATRIX; NO OIL INDICATORS PRESENT. 14100' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY; MODERATELY HYDROPHILIC; MUSHY CONSITENCY; IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; WAXY TO DULL LUSTER; CLAYEY TO SILTY TEXTURE. 14130' SAND = LIGHT GRAY OCCASIONALLY VERY PALE ORANGE; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE LOWER; SUBROUND OCCASIONALLY SUBANGULAR; MODERATELY SPHERICITY; MODERATE OCCASIONALLY POOR SORTING; CHIP TO IMPACTED OCCASIONAL POLISHED TEXTURE; NON TO VERY SLIGHT SILIC CEMENT; MODERATELY CLAY/ASH MATRIX; BOTH GRAIN AND MATRIX SUPPORTED; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC AND VARIOUS LITHiC FRAGMENTS; FAIR OCCASIONALLY POOR POROSITY AND PERMEABILITY; NO OIL INDICATORS. 14190' COAL = GRAYISH BLACK TO BLACK; FIRM OCCASIONALLY HARD; RESINOUS TO EARTHY LUSTER; SMOOTH TO MATTE TEXTURE; SUBCONCH TO HACKLY FRACTURE; COMPOSED OF BITUMINOUS COAL. 14215' TUFFACEOUS SILTSTONE = LIGHT GRAY TO PINKISH GRAY; POOR OCCASIONALLY MODERATE IND; SLIGHTLY SECTILE; EARTHY [::l EPOCH 3 7 Forest Oil Corporation Redoubt Unit #2 FRACTURE; SUB NODULAR HABIT; MODERATE EARTHY LUSTER; SILTY OCCASIONALLY CLAYEY TEXTURE; THICK BEDS OF GRADATIONAL SILTS; GENERALLY COMPOSED OF 70% SILT, 20% CLAY, 10% ASH. 14255' COAL = GRAYISH BLACK TO BLACK OCCASIONALLY GRADING TO VERY CARBONACEOUS SHALE; FIRM OCCASIONALLY HARD; RESINOUS TO EARTHY LUSTER; SMOOTH TO MATTE TEXTURE; SUBPLANAR (CARB SHALE) TO HACKLY FRACTURE; OCCASIONAL REDDISHBRN HUES. 14285' TUFFACEOUS SlLTSTONE = LIGHT GRAY TO PINKISH GRAY; POOR TO MODERATE INDURATED BRITTLE TO STIFF; EARTHY FRACTURE; SUBNODULAR HABIT; MODERATE EARTHY LUSTER; SILTY TEXTURE; MASSIVE GRADATIONAL SILTS; SCATTERED DETRITAL SANDS AND ASHY SANDSTONES. NOTE: FROM 4/7/01 TO 4/15/01, WIPE HOLE, RUN E-LOGS, CLEAN OUT HOLE, RUN 7.625" CASING, CEMENT, DRILL OUT. NOTE: SAMPLES FROM 14320'-14400' CONTAIN HIGH AMOUNTS OF CEMENT. 14350' SAND = PINKISH GRAY TO VERY PALE ORANGE; CLAST SIZE RANGES FROM COARSE UPPER TO MEDIUM LOWER BECOMING FINER AT 14420' (MED LOWER TO FINE LOWER); SUBROUND TO SUBANGULAR; MODERATE SPHERICITY; POOR BECOMING MODERATE SORTING WITH DEPTH; GENERALLY POLISHED BECOMING IMPACTED AND CHIPPED WITH DEPTH; NON TO VERY SLIGHT SILICA CEMENT; MODERATE SILT AND ASH MATRIX; GENERALLY MATRIX SUPPORTED; BECOMING MATRIX AND GRAIN SUPPORTED WITH FINER GRAINS AT 14420'; COMPOSED OF 60% QUARTZ, 30% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; FAIR TO POOR POROSITY WITH POOR PERMEABILITY; BECOMING FAIR OCCASIONALLY GOOD POROSITY AND PERMEABILITY AT 14420'; NO OIL INDICATORS/OIL BASE MUD. 14430' SANDSTONE/CONGLOMERATE SAND = VERY PALE ORANGE TO GRAYISH ORANGE PINK OCCASIONALLY LIGHT BROWN; CLAST SIZE RANGES FROM PEBBLE TO VERY COARSE TO COARSE LOWER GRADING TO MEDIUM SAND AS MATRIX; SUBROUND PEBBLES TO SUBANGULAR SANDS; OVERALL POORLY SORTED; IMPACTED MATRIX SANDS WITH POLISHED AND SCARRING PEBBLES; SLIGHT TO MODERATE SILICA CEMENT BECOMING DENSE IN PARTS; SLIGHT OCCASIONAL MODERATE SILT AND CLAY PACKED MATRIX; DOMINANTLY GRAIN SUPPORTED WITH SECONDARY MINOR MATRIX SUPPORT; COMPOSED OF 30% QUARTZ, 60% CHERT, 10% METAMORPHIC (ARGILLITE); FAIR ESTIMATED POROSITY AND PERMEABILITY; PATCHY TO EVEN LIGHT BROWN OIL STAIN BEGINING AT 14453' INCREASING TO EVEN STAINS AT 14460' TO 14475' AND AGAIN AT 14480' TO 14493' AND 14499' TO 14507'. [:l EPOCH 38 Forest Oil Corporation Redoubt Unit #2 14520' CONGLOMERATE SAND/CONGLOMERATE = LIGHT BROWN TO GRAYISH ORANGE PINK; CLAST SIZE RANGE PEBBLE TO COARSE TO MEDIUM MATRIX SANDS; SUBROUND AND POLISHED IN UPPER FRACTION TO SUB ANGULAR IMPACTED MATRIX SANDS; DOMINANTLY GRAIN SUPPORT WITH SECONDARY MATRIX SILTS AND CLAY SUPPORT; COMPOSED OF 20-30% CHERT, 40-70% QUARTZ, 30% METAMORPHIC (ARGILLITE) FELD, TUFF; PATCHY OIL STAINS IN SAMPLES: 14510-520', 14530-555 SCATTERED DENSE THIN BEDS OF SALT AND PEPPER SANDSTONE. NOTE: TRIP OUT AND DRILL 27' BYPASS LOOSE CONGLOMERATE AND OPEN HOLE. 14595' SANDSTONE = VERY LIGHT GRAY TO SALT AND PEPPER; CLAST SIZE RANGES FROM FINE UPPER TO LOW OCCASIONALLY GRADING TO SILT; SUBANGULAR; POOR TO MODERATE SPHERICITY; IMPACT TEXTURE; SLIGHT TO MODERATE SILICA CEMENT; OVERALL DENSE; SLIGHT CLAY MATRIX; DOMINANTLY GRAIN SUPPORT; COMPOSED 50% QUARTZ, 20% CHERT, 30% METAMORPHICS, TUFF AND GREENSTONE; POOR TO FAIR POROSITY AND PERMEABILITY; 100% DENSE SILT AT 14594-597' WITH DEAD OIL TAR; 50% SILT 50%; INTERBEDDED CARBONACEOUS SHALE (LAMINAE) 14600-603' WITH VISIBLE DEAD OIL TAR. 14660' SANDSTONE = DUSKY BROWN TO LIGHT BROWN; GRADING FROM MEDIUM GRAINS TO COARSE LOWER; OCCASIONALLY COARSE UPPER SUBANGULAR; MODERATELY SPHERICITY; POOR SORTING; CHIPPED TEXTURE; SLIGHT TO MODERATELY CRUMBLY; DOMINANTLY GRAIN SUPPORTED; TRACE COAL MICRO LAMS AT 14668'; COMPOSED OF 75%QTZ 10% CHERT, 15% METAMORPHIC GOOD PORO AND PERMEABILITY; GOOD BROWN EVEN OIL STAIN AND MODERATE TO GOOD PETROLEUM ODOR FROM 14663'-14674'. NOTE: DRILL AND SLIDE FORMATION AT 14689' 14705' SAND = PINKISH GRAY; CLAST SIZE RANGE COARSE LOWER TO FINE UPPER; SUBANGULAR; MODERATE TO POOR SORTING; CHIPPED TO IMPACTED TO FROSTED TEXTURE; NO VISIBLE MATRIX; DOMINANTLY GRAIN SUPPORT; ABUNDANT BIT IMPACTED CUTTINGS; NO OIL INDICATORS WITH OIL BASE MUD. 14735' SANDSTONE = VERY LIGHT GRAY; CLAST SIZE RANGES FROM COARSE TO UPPER FINE GRAINED MODERATELY CRUMBLY; ANGULAR TO SUBANGULAR; POOR TO MODERATE SPHERICITY; GRAINED SUPPORTED; SILTY AND CLAY MATRIX; POORLY PRESERVED IN SAMPLES; ABUNDANT DARK GRAY MODERATELY HARD, EPOCH 3 9 Forest Oil Corporation Redoubt Unit #2 CARBONACEOUS SHALE IN SAMPLES WITH ABUNDANT PLANT IMPRESSIONS; ABUNDANT GREENSTONE FRAGMENTS; 60% QTZ; 20% CHERT 20% METAMORPHICS; OIL INDICATORS MASKED BY OIL. NOTE: TRIP OUT AT 14800' TEST BOPE, RUN LOGS. INJECT CUTTINGS (6 HRS), RUN TEMP LOG. 14825' CONGLOMERATIC SANDSTONE = VERY LIGHT GRAY; CLAST SIZE RANGES FROM PEBBLE TO COARSE TO MEDIUM; DOMINANTLY MEDIUM GRAINED; FRIABLE; ANGULAR TO SUBROUNDED; LOW TO MODERATELY SPHERICITY; SILICEOUS CEMENT; GRAIN SUPPORTED; 70% QUARTZ; 20% CHERT; 10% METAMORPHICS; ABUNDANT MEDIUM BROWN WAXY BITUMEN MATERIAL AT 14827' TO 14830'. NOTE: SANDSTONE AT 14888' EXHIBITED THE BEST OIL STAINING, FLUORESCENCE AND CUTS OF CORE #10. 14885' SANDSTONE = LIGHT BROWN (OIL STAINING) SPECKLED WITH BLACK LITHIC FRAGMENTS; MEDIUM TO FINE GRAINED; SUBANGULAR TO SUBANGULAR; MODERATELY SPHERICITY; FRIABLE WITH GOOD POROSITY AND PERMEABILITY; GRAIN SUPPORTED WITH SILICIC CEMENT; EVEN BRIGHT YELLOW FLUORESCENCE IN FRESHLY BROKEN CORE; OIL BASE MUD CONTAMINATION IS PRESENT ON MOST CHIPS. 14905' SANDSTONE/CONGLOMERATE SAND = VERY PALE YELLOWISH BROWN TO LIGHT BROWNISH GRAY; CLAST SIZE RANGES FROM PEBBLE TO MEDIUM GRAINS; SUBROUND OCCASIONALLY SUBANGULAR; POOR TO VERY POOR SORTING (MODERATE SORTING IN SANDSTONES); POLISHED OCCASIONAL CHIP TEXTURE; NON TO VERY SLIGHT SILICA CEMENT; NON TO SLIGHT WHITE KAOLINTE MATRIX AT 14940', INCREASING TO MODERATE TO ABUNDANT AT 14950'; DOMINANTLY GRAIN SUPPORTED WITH MINORR MATRIX SUPPORTED LOOSELY ATTACHED; COMPOSED OF 50% QUARTZ, 20% CHERT, 30% METAMORPHIC, IGNEOUS, FELDSPAR, GREENSTONES; GOOD POROSITY AND PERMEABILITY AT 14940, DECREASING TO MODERATELY AT 14965'; GOOD OIL STAIN AT 14946, 14948, 14955' AND 14961'; EVEN BROWN STAIN; LARGE COAL FRAGMENTS IN CONGLOMERATE MATRIX 14968'. 15010' SANDSTONE = LIGHT GRAY TO OFFWHITE; LOWER COARSE TO LOWER MEDIUM GRAINED; MODERATELY HARD AND SILICEOUS FROM 15000' TO 15009'; BECOMING FRIABLE WITH MASSIVE KAOLINITE FILL WITH GOOD POROSITY FROM 15009' TO 15021'; ANGULAR TO SUBANGULAR; LOW TO MODERATELY SPHERICITY; GRAIN SUPPORTED; 10% CHERT; 20% BLACK LITHIC FRAGMENTS (CARBONACEOUS SHALE TO COAL TO METAMORPHIC FRAGMENTS); MINOR AMOUNTS OF BROWN BIOTITE AND CHLORITE; NO VISIBLE STAIN ON CORE FROM 15000' TO 15021'; POOR SCATTERED LIGHT BROWN OIL STAIN FROM 15021' TO EPOCH 40 Forest Oil Corporation Redoubt Unit #2 15030' IN A CONGLOMERATIC SANDSTONE INTERVAL; BEST OIL STAIN AND FLUOR (CORE #16) 15021'. CORE #18 - COAL AT TOP (15060') AND BOTTOM 15087.5'. PROGRESSIVE INCREASE IN GRAIN SIZE AND POROSITY DOWN THE CORE FROM ARGILLACEOUS SILTSTONE (15063'), FINE GRAINED SANDSTONE, MEDIUM GRAINED SANDSTONE, CONGLOMERATIC SANDSTONE TO CONGLOMERATE (OVER COAL) AT 15087'. HEAVY EVEN LIGHT BROWN OIL STAINING AT THE BOTTOM OF THE CORE IN THE CONGLOMERATE SANDSTONE AND CONGLOMERATE 15084' -15087'. NOTE: TRIP FOR DRILL BIT AT 15088'. 15105' SILTSTONE = MEDIUM GRAY; FIRM TO MODERATELY HARD; MASSIVE TO SLIGHTLY PLATY CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; SILICEOUS AND ARGILLACEOUS; SILTY TEXTURE; WITH SOME BLACK CARBONACEOUS PLANT MATERIAL; GRADING TO FINE GRAINED SANDSTONE. 15140' COAL AND CARBONACEOUS SHALE = BLACK TO DARK BROWN; MODERATELY HARD; PLATY CUTTINGS; BLOCKY TO PLANAR FRACTURE; DULL TO VITREOUS LUSTER; SMOOTH TO ROUGH TEXTURE; INTERBEDDED WITH SILTSTONE. 15165' SANDSTONE = LIGHT GRAY; PREDOMINANTLY LOOSE GRAINS; LOWER COARSE TO FINE GRAINED; POORLY SORTED; SUBANGULAR TO SUBANGULAR; ABUNDANT CLAY WITH SOME SILICA CEMENT; GRAIN SUPPORTED; OCCASIONAL BLACK COALY MATERIAL; INCREASING LOOSE GREEN GRAINS; TRACE BRICK RED VOLCANIC SPECKS AT 15200'; INTERBEDDED WITH MEDIUM GRAY TO OCCASIONALLY MEDIUM BROWN ARGILLACEOUS TO SILICEOUS SILTSTONES. 15230' COAL = GRAYISH BLACK; FIRM; MODERATELY EARTHY LUSTER; SLIGHT GRITTY TO OCCASIONAL WOODY TEXTURE; HACKLY TO BLOCKY FRACTURE; COMPOSED OF VERY CARBONACEOUS SHALE AND LIGNITIC COAL; MICRO LAMINAE OF CARBONACEOUS SHALE INTBD. NOTE: 10 STAND WIPER TRIP AT 15254' 15250' SILTSTONE = OFFWHITE TO VERY LIGHT GRAY; MEDIUM GRAY; TRACE MEDIUM BROWN; SOFT TO SLIGHTLY HARD IN SILIClC SPECIMENS; MASSIVE CUTTINGS; IRREGULAR FRACTURE; SILTY TEXTURE; DULL TO SLIGHTLY VITR LUSTER; ABUNDANT BLACK CARBONACEOUS STREAKS; MEDGRAY SPECIMENS ARE COMMONLY VERYSILI AND ARGILLACEOUS; INTERBEDDEDW/OFFWHITE SANDY INTERVALS WITH UPPER MEDIUM TO VERY FINE QTZ SUPPORTED IN ASH AND CLAY MATRIX. EPOCH 4 ] Forest Oil Corporation Redoubt Unit #2 15300' SANDSTONEISILTSTONE = PREDOMINANTLY LOOSE GRAINS; OFFWHITE TO LIGHT GRAY; VERY SOFT; ASH AND/WHITE CLAY IN MATRIX; MEDIUM GRAY; POORLY PRESERVED; PREDOMINANTLY FINE GRAINED TO SILT SIZED GRAINS; LOOSE LOWER MEDIUM QUATZ GRAINS; ANGULAR TO SUBANGULAR; SILICA TO WHITE CLAY AND ASH MATRIX; OCCASIONAL SCATTERED CARBONACEOUS MATERIAL; GRADING TO SILTSTONE; NO OIL INDICATORS. NOTE: T.D = 15325' (12587' TVD) ON 5/17/2001. EPOCH 42 ,. Forest Oil Corporation Redoubt Unit #2 MUD RECORD FOREST OIL INC.EPOCH REDOUBT SHOALS, COOK INLET DALLY MUD REPORTS OSPREY PLATFORM REDOUBT UNIT # 2 DATE DEPTH WEIGHT VIS PV YP GELS HTHP Fil CAKE SOLIDS OIL/WATER SAND pH CI Ca 2/24/01 178 8.8 180 15 :5838/51/57 NA 4/ 4.50 0/94 0.250 8.5 2400 120 2/25/01 750 9.0 95 11 33 16/17/22 NA 4/ 6.00 0~94 0.750 10.6 2300 360 2/26/01 948 8.7 120 8 49 22/26/2g NA <2/ 3.00 0~97 TR 8.9 400 40 2/27/01 1980 9,2 77 15 33 23/26/28 NA 2/ 6.50 0/93.5 TR 8.8 700 40 2/28/01 2913 9.4 119 16 36 26/48/56 NA 3/ 6.50 0/93.5 0.300 8.0 400 40 3/1/01 3150 9.6 120 18 34 18/38/58 NA 3/ 8.00 0~92 0.300 8.8 400 40 3/2/01 3226 9.5 64 17 24 12/34/58 NA 3/ 8.00 0/92 0.300 8.8 400 40 3/3/01 3212 9.3 44 11 9 3/11/17 NA 3/ 7.00 0~93 0.200 9.0 400 100 3/4/01 3212 8.9 57 13 14 5/18/21 NA 2/ 4.00 0~94 0.200 9.0 400 40 3/5/01 3109 9.0 38 8 6 11/24/28 NA 2/ 4.50 0~96 0.250 11.0 400 80 3/6/01 4031 9.1 40 7 11 5/25/40 NA 2/ 5.00 0~95 0.250 ,11.0 400 40 I ,, 3/7/01 5306 9.6 43 15 12 5/13/20 NA 2/ 7.00 0/93 0.250 9.0 400 40 3/8/01 6313 9.8 47 19 21 10/22/26 NA 2/ 8.00 0~92 0.250 8.5 400 40 3/9/01 7159 9.4 43 '11 16 9/12/16 NA 2/ 7.00 TR/93' 0.125 8.3 450 20 , , 3/10/01 7580 9.5 43 13 18 9/13/16 NA 2/ 7.50 TR/92.5 0.250 8.3 350 20 3/11/01 7830 9.5 44 13 18 10/13/17 NA 2/ 7.00 mR/93 0.125 8.5 350 40 3/12/01 8143 9.3 41 13 158/11/17 NA " 2/ 6.00 mR/94 0.125 8.8 300 40 3/13/01 8330 9.3 41 11 13 7/9/13 NA 2/ 6.00 mR/94 0.125 8.4 300 40 , , 3/14/0t 8487 9.3 45 13 19 10/13/18 NA 2/ 6.00 TR/94 0.125 8,4 300 40 3/15/01 8880 9.'3 42 13 15 9/11/15 NA 2/ 6.50 TR/94 0.125 8.7 300 40 3/16/01 9029 9.4 45 12 15 8/12/16 NA 2/ 6.50 TR/94 0.125 8.7 300 40 3/17/01 9029 9.6 48 16 17 9/18/23 NA 2/ 7.50 TR/93 0.125 9.1 300 40 3/18/01 9029 9.5 46 19 16 9/13/21 NA 2/ 7.50 TR/93 0. i25 8.8 300 40 3/19/01 SWITCHING OVER TO OIL BASED MUD SALT 3/20/01 9029 9.0 95 21 13 6/11/15 7.5@250 /1 8.71 85/1'5 NA NA 21000 19.01 3/21/01 9029 9'10 120 21 13 6/11/15 7.5@250 /1 8.71 86/14 NA NA 21000 20,82 3/22/01 9751 9.0 80 26 18 10/14/1§ 10.3@350 /1 9.39 80/20' NA NA 29500 20.14 , , 3/23/01 10255 9.0 65 18 115 8/14/14 10.5@350 /1 9.23 80/20 NA NA 33000 22.79 3/24/01 10746 9.1 80 21 19 9/15/16 5.5@300 /1 11.30 82/18 NA NA 31000 23.27 3/25/01 11194 9.2 100 15 30 11/16/18 5@300 '/1 10.71 82/16 NA NA 33000 24.40 3/26/01 .11476 9.2 90 19 14 9/14/15 5@300 /1 10.75 85/15 NA NA 32000 24.42 3/27/01 12000 9.2 85 20 14 11/14/16 5(~300. /2 11.22 84/16 NA NA 32000 26.35 3/28/01 12234 9.3 100 20 14 12/15/17 5~300 ~2 11.69 83/17 NA NA 33000 25.61 3/29/01 12295 9.4 87 21 18 t0/14/15 6~300 ~2 13.00 70/12 NA NA 29000 21.07 [:l EPOCH 43 Forest Oil Corporation Redoubt Unit #2 DATE DEPTH WEIGHT VIS PV YP GELS HTHP Fil CAKE SOLIDS OlL/WATERI SAND pH CI SALT 3/30/01 12800 9.3 86 18 14 8/12/14 5~,300 ~ 11.50 83/17 NA NA 30000 23.84 3/31/01 12815 9.3 116 19 14 8/12/ 5~300 ~2 10.33 83/17 NA NA 30000 23.84 4/1/01 13100 9.4 78 16 13 8/12/14 5~,300 ~2 11.11 86/14 NA NA 28000 26.75 4/2/01 13225 9.6 98 16 12 9/12/14 6~300 ~2 11.50 86/14 NA NA 25000 24.59 4/3/01 13480 9.5 74 17 15 10/13/15 5~300 ~2 12.00 86/14 NA NA 25500 24.96 4/4/01 13823 9.4 70 17 13 8/12/14 6~,300 ~2 10.54 84/16 NA NA 25000 21.84 4/5/01 13823 9.5 75 17 13 8/13/14 5~,300 ~2 11.21 86/14 NA NA 25000 23.84 4/6/01 14214 9.5 71 18 14 12/16/18 6~,300 ~2 12.00 86/14 NA NA 24000 23.84 4/7/01 14320 9.6 80 18 14 12/17/20 6~,300 ~2 11.00 86/14 NA NA 2500i3 23.84 4/8/01 14320 9.6 95 18 15 12/17/21 6~,300 ~2 11.00 86/14 NA NA 25000! 23.84 4/9/01 14320 9.6 78 17 12 11/17/19 7~,300 ~ 11.60 86/14 NA NA 23000 23.07 4/10/01 14320 9.6 90 17 12 11/18/20 7~,300 ~2 11.60 86/14 NA NA 23000 23.07 4/11/01 14320 9.7 80 19 12 10/15/19 7@300 ~2 11.70 88/12 NA NA 21000 23.84 4/12/01 14320 9.7 80 19 12110/15/20 7~,300 ~2 11.69 87/13 NA NA 21000 23.00 4/13/01 14320 9.7 84 20 11 10/15/20 7~,300 ~2 11.69 87/13 NA NA 21000 21.00 4/14/01 14320 9.7 94 20 11 10/15/20 7~,200 ~2 11.69 87/13 NA NA 21000 23.00 4/15/01 14340 9.6 77 19 12:10/14/19 6~200 ~ 11.19 88/13 NA NA 21000 23.00 4/16/01 14420 9.5 75 19 11 8/15/17 5~250 ~ 10.20 87/13 NA NA 21000 21.50 4/17/01 14420 9.5 79 21 10 8/15/17 4~250 ~ 10.80 87/13 NA NA 21000 22.69 4/18/01 14475 9.5 76 21 10 9/16/17 4~250 ~ 11.00 88/12 NA NA 20000 22.15 4/19/01 14537 9.5 74 21 8 7/12/15 2~.250 ~2 11.00 85/15 NA NA22000 20'94 4/20/01 14558 9.5 74 20 11 7/11/14 2~.250 \1 10.24 87/13 NA NA 20000 20.69 4/21/01 14567 9.5 73 20 12 8/13/18 2~250 \1 t0.74 87/13 NA NA20000 21.39 4/22/01 14567 9.5 76 20 11 7/12/16 2~..250 \1 10.75 86/14 NA NA 20000 20.03 4/23/01 14594 9.5 76 20 11 8/14/18 2~250 \1 10.70 87/13 NA NA 20000 21.39 4/24/01 14607 9.5 82 19 12 7/14/19 1~250 \1 10.74 87/13 NA NA 20000 21.39 4/25/01 14645 9.5 73 19 10 4/14/15 1~..250 \1 10.75 86/14 NA NA 20000 20.03 4/26/01 14674 9.5 90 21 10 6/10/12 2~.250 ~ 10.84 84/16 NA NA21000 19.01 4/27/01 14689 9.5 90 20 9 5/10/11 2~250 \1 10.70 84/16 NA NA 20000 18.27 4/28/01 14725 9.5 82 22 10 6/11/12 2~.250 \1 11.26 84/16 NA NA 20000 18.27 4/29/0i 14727 9.5 ' '90 21 11 6/11/12 2~.250 \1 12.00 84/16 NA NA 20000 18.27 4/30/01 14727 9.5 90 20 12 7/11/12 2~250 \1 11.38 84/16 NA NA 20000 18.27 5/1/01 14727 9.5' 87 20 11 7/11/12 2~.250 \1 11.26 84/16 NA NA20000 18.27 5/2/01 14800 9.5 95 21 11 7/11/12 ~ \1 11.25 85/15 NA NA 20000 19.40 5/3/01 14800 9.5 91 20 12 6/11/12 2~250 \1 12.00 84/16 NA NA17000 15.97 5/4/01 14812 9.5 92 21 11 7/11/12 2~.250 \1 11.22 84/16 NA NA 21000 19.01 5/5/01 14844 9.5 94 21 12 7/11/12 2~.250 \1 :11.34 85/15 NA NA 20000 19.40 5/6/01 14894 9.5 91 21 13 7/11/12 2~.250 \1 12.00 85/15 NA NA 19000 18.61 5/7/01 14912 9.5 98 22 12 7/11/12 2~250 \1 11.30 85/15 NA NA 19000 18.61 5/8/01 14920 9.5 97 21 12 7/11/12 2~250 \1 11.33 86/14 NA NA 18000 19.01 5/9/01 '14934 9.5 81 21 12 7/11/12 2~.250 \1 11.25 85/15 NA NA 20000 19.40 5/10/01 14968 9.5 85 22 13 8/12/13 2~.250 \1 11.06 83/17 NA NA 25000 20.69 5/11/01 14978 9.5 100 24 18 10/15/16 2~250 \1 10.92 83/17 NA NA 28000 22.61 5/12/01 15000 9.5 87 24 13 7/10/11 2~.250 \1 10.83 83/17 NA NA 30000 23.84 5/13/01 15038 9.5 87 22 13 7/11/12 2~250 \1 10.42 84/16 NA NA 28000 22.61 5/14/01 15059 9.5 94 2314 7/11/12 2~250 \i 10.84 83/17 NA NA 30000 23.84 5/15/01 15078 9.5 90 24 12 7/11/12 1~250 \1 10.86 84/16 NA NA 29000 24.48 EPOCH 44 ~ Forest Oil Corporation Redoubt Unit #2 DATE DEPTH WEIGHT ViS PV YP GELS HTHP Fil CAKE SOLIDS OIL/WATER SAND pH CI SALT 5/16/01 15088 9.5 88 21 12 7/12/16 1~250 \1 10.84 82/18 NA NA 30000 22.69 5/17/01 15215 9.6 78 22 9 5/10/12 1~.250 \1 10.95 81/19 NA NA 28000 20.49 5/18/01 15325 9.5 76 20 8 5/10/11 1~250 \1 10.84 82/18 NA NA 30000 22.69 5/19101 15325 9.5 79 18 112 5/11/13 1~250 \1 10.84 82/18 NA NA 30000 22.69 5/20/01 15325 9.5 80 19 12 6/11/13 1~.250 \1 10.84 82/18 NA NA 30000 22.69 EPOCH 45 Forest Oil Corporation Redoubt Unit #2 SURVEY RECORD FOREST OIL INC. SURVEY OSPREY PLATFORM SUMMARY REDOUBT UNIT # 2 MEASURED HOLE VERTICAL COORDINATES DOGLEG DEPTH TVD ANGLE AZIMUTH SECTION , N I+~ or S I') E (+t or W t') SEVERITY 82.00 82.00 0.25 100.00 0.2 0.0 0.2 0.30 115.00 115.00 0.25 310.00 0.2 0.0 0.2 1.46 172.00 172.00 0,10 230.00 0.0 0.1 0.1 0,44 202.00 202.00 0.10 170.00 0.0 0,0 0.0 0.33 231.00 231.00 0.50 256.00 0.0 0.0 -0.1 1.73 , , 261.00 261.00 0.90 262.00 -0.3 -0.1 -0.4 1.35 291.00 291.00 0.80 270.00 -0.6 -0.1 -0.9 0.52 , ,, 350.00 350.00 1.25 320.00 -1.6 0.3 -1.7 1.62 413.00 413.00 1.60 336.00 -3.0 1.7 -2,5 0.84 500.00 499.90 1.90 89.00 -2.9 2.8 -1.6 3.36 530.00 529.90 2.00 96.00 -2.0 2.8 -0,5 0.86 560.00 559.90 2.20 112.00 -1.0 2.5 5.0 2.06 589.00 588.90 3.00 114.00 0.3 2.0 1.7 2.78 651.00 650.80 2.10 140.00 3.0 0.4 3.9 2.33 740.00 739.80 1.50 177.00 5,3 -2.0 5,0 1.43 , , 801.00 800.70 2.10 209.00 5.9 -3.7 4,5 1.88 890.00 889.60 3.40 196.00 6.9 -7.7 3,0 1.61 , , 980.00 979.40 5.00 180.00 10.0 -14.2 2.3 2.19 1070.00 1069.00 6.20 158.00 16.4 -22.6 4.1 2.71 1168.00 1166.10 9.00 145.00 2.8 -33.8 10.5 3,34 1259.00 1255.70 11.50 138.00 43.5 -46,4 20.7 3.06 1355.00 1349.30 14.00 132.00 64.4 -61.3 35.7 2.94 EPOCH 46 Forest Oil Corporation Redoubt Unit #2 MEASURED HOLE VERTICAL COORDINATES DOGLEG DEPTH TVD ANGLE AZIMUTH SECTION N (+) or S (-) E (+) or W (-) SEVERITY 1473.54 1463.40 17.22 133.57 96.0 -83.0 59.1 2.74 1572.26 1557.00 20.04 132.01 127.2 -104.4 82.2 2.90 1666.65 1645.10 22.01 126.35 161.0 -125.7 108.5 3.00 1762.27 1733.00 24.26 123.64 198.5 -147.2 139.3 2.60 1858.79 1820.10 26.74 124.91 240.1 -170.6 173.6 2.63 1954.87 1904.80 29.65 122.26 285.4 -195.7 211.4 3.30 2049.32 1985.50 32.97 120.03 334.4 -221.0 253.5 3.72 i i i 2146.80 2066.1 35.43 119.67 389.0 -248.3 301.0 2.53 2240.54 2142.8 34.84 120.38 442.7 -275.2 347.7 0.77 2334.04 2219.5 34.85 122.90 496.0 -303.3 393.2 1.54 2430.43 2297.9 36.28 124.36 552.1 -334.3 439.8 1.73 2523.87 2372.5 37.88 124.22 608.4 -366.1 486.4 1.71 i 2622.09 2450.6 36.70 124.06 667.9 -399.5 535.6 1.21 2717.95 2527.3 37.03 124.48 725.4 -431.8 583.1 0.43 2815.41 2604.4 38.40 124.35 785.0 -465.5 632.3 1.41 2910.99 2679.0 38.94 124.22 844.7 -499.2 681.7 0.57 3002.84 2750.9 38.07 124.16 901.9 -531.3 729.0 0.95 3099.00 2827.0 37.31 123.76 960.7 -564.2 777.7 0.83 3196.00 2905.1 35.42 123.35 1018.2 -595.9 825.7 1.96 ...... 3290.39 2982.0 35.45 124.08 1072.9 -626.3 871.2 0.45 3384.41 3058.0 36.69 124.80 1128.2 -657.6 916.8 1.39 3481.60 3135.2 38.10 125.00 1187.3 -691.4 965.2 1.46 , , 3576.75 3211.0 36.25 125.87 1244.7 -724.7 1012.1 2.02 3671.09 3286.7 37.01 125.26 1301.0 -757.5 1057.9 0.89 3767.05 3362.7 38.29 124.28 1359.6 -790.9 1106.0 1.47 3864.78 3439.1 38.96 124.40 1420.0 -825.3 1156.4 0.69 3959.00 3512.0 39.50 124.93 1480.2 -859.2 1205.4 0.67 , , 4058.16 3588.3 39.93 125.04 1543.6 -895.5 1257.3 0.44 4151.10 3659.7 39.79 125.59 1603.2 -929.9 1305.9 0.41 4245.80 3732.5 39.70 125.11 1663.7 -965.0 1355.3 0.34 [::l EPOCH 47 Forest Oil Corporation Redoubt Unit #2 MEASURED HOLE VERTICAL COORDINATES DOGLEG DEPTH TVD ANGLE AZIMUTH SECTION N (+) or S (-) E (+) orW (-) SEVERITY 4342.30 3806.9 39.37 125.17 1725.1 -1000.3 1405.5 0.34 4436.33 3879.7 39.19 124.70 1784.7 -1034.4 1454.3 0.37 4532.58 3954.3 39.22 125.04 1845.5 -1069.2 1504.3 0.23 4629.77 4029.8 38.72 125.90 1906.6 -1104.3 1554.3 0.52 4726.97 4105.8 38.54 125.06 1967.3 -1139.2 1603.9 0.19 4819.94 4178.6 38.25 125.22 2025.0 -1172.4 1651.2 0.33 4917.53 4255.5 37.85 124.59 2085.20 -1206.8 1700.5 0.57 5012.48 4330.6 37.64 124.74 2143.30 -1239.9 1748.3 0.24 5108.53 4406.6 37.64 124.59 2202.00 -1273.3 1796.5 0.10 ,, 5204.28 4482.6 37.36 124.83 2260.30 -1306.5 1844.5 0.14 5298.62 4557.5 37.49 124.84 2317.60 -1339.2 1891.5 0.14 .... 5393.29 4632.6 37.53 124.32 2375.20 -1371.9 1939.0 0.34 5490.01 4709.4 37.23 124.68 2433.90 -1405.2 1987.4 0.38 5586.40 4786.2 37.16 125.04 2492.20 -1438.5 2035.2 0.24 5681.31 4861.9 37.03 125.06 2549.50 -1471.4 2082.0 0.14 5774.85 4936.4 37.44 124.64 2606.10 -1503.7 2128.5 0.52 ,, 5871.50 5013.0 37.67 125.02 2665.00 -1537.4 2176.9 0.34 5966.80 5088.5 37.60 124.88 2722.20 -1570.7 2224.5 0.12 6035.71 5143.0 37.88 124.82 2765.30 -1594.8 2259.2 0.41 , , 6131.90 5218.9 37.97 124.65 2824.50 -1628.5 2307.7 0.14 6228.45 5295.0 37.91 124.64 2883.80 -1662.2 2356.6 0.06 6324.24 5370.9 37.34 125.12 2942.30 -1695.7 2404.6 0.67 ..... 6419.69 5446.9 37.16 125.42 3000.00 -1729.0 2451.7 0.27 , , 6513.74 5521.9 36.89 125.55 3056.70 -1761.9 2497.8 0.30 6611.74 5600.6 36.39 125.58 3115.20 -1795.9 2545.4 0.51 6707.22 5677.5 36.23 125.50 3171.70 -1828.8 2591.4 0.17 6802.23 5754.3 35.93 125.69 3227.70 -1861.3 2636.9 0.34 6896.12 5830.5 35.64 126.18 3282.60 -1893.6 2681.4 0.43 6992.99 5909.0 35.97 125.55 3339.20 -1926.8 2727.3 0.51 7087.93 5985.8 36.20 125.60 3395.20 -1959.3 2772.8 0.24 EPOCH 48 Forest Oil Corporation Redoubt Unit #2 I MEASURED ! IHOLE VERTICAL ~COORDINATES DOGLEG DEPTH 'FVD ANGLE , AZIMUTH SECTION U (+) or S (-) E (+) or W (-) SEVERITY 7186.52 6065.2 36.44 124.87 3453.50 -1993.0 2820.5 0.50 7280.12 6140.8 35.82 125.96 3508.70 -2025.0 2865.5 0.95 7376.99 6219.4 35.64 125.81 3565.30 -2058.0 2911.3 0.21 7474.40 6298.1 36.61 125.32 3622.70 -2091.5 2958.0 1.04 7566.09 6371.7 36.59 125.40 3677.40 -2123.2 3002.6 0.06 7662.97 6449.7 36.28 125.65 3734.90 -2156.6 3049.4 0.35 7757.79 6526.2 35.99 125.64 3790.80 -2189.2 3094.4 0.31 7852.13 6602.7 35.70 125.33 3846.08 -2221.2 3139.9 0.37 7950.49 6682.7 35.44 124.89 3903.30 -2254.1 3186.7 0.37 8002.40 6724.7 36.68 124.72 3933.85 -2271.6 3211.7 2.40 8044.35 6758.2 37.30 124.08 3959.09 -2285.9 3232.6 1.74 8085.82 6791.2 37.34 123.90 3984.22 -2299.9 3253.4 0.28 8136.76 6831.6 37.64 123.22 4015.22 -2317.1 3279.2 1.00 8187.25 6871.6 37.44 124.64 4045.97 -2334.2 3304.8 1.75 ,, 8234.68 6909.3 37.38 124.24 3328.55 -2350.5 4074.8 0.53 8280.05 6945.3 37.38 123.62 3351.41 -2365.9 4102.3 0.83 8328.70 6984.2 36.62 124.43 3375.68 -2382.3 4131.6 1.86 8412.50 7051.7 36.13 123.08 3417.00 -2409.9 4181.3 1.11 8457.43 7088.0 35.82 123.29 3439.09 -2424.3 4207.7 0.76 8523.11 7141.4 35.47 123.72 3471.00 -2445.5 4245.9 0.65 , , 8564.71 7175.1 36.27 123.63 3491.28 -2459.0 4270.3 1.94 8617.46 7217.5 36.94 123.63 3517.47 -2476.4 4301.8 1.27 , , 8666.82 7256.8 37.34 123.59 3542.29 -2492.9 4331.5 0.81 , , 8713.32 7293.8 37.17 123.66 3565.73 -2508.5 4359.7 0.37 8808.94 7370.2 36.84 123.59 3613.66 -2540.3 4417.2 0.35 8903.72 7446.5 35.84 123.92 3660.36 -2571.6 4473.4 1.08 8957.30 7490.1 35.38 123.09 3686.37 -2588.8 4504.6 1.24 9081.95 7590.6 37.12 122.93 3748.17 -2628.9 4578.2 1.40 9178.61 7667.7 37.04 123.20 3797.01 -2660.7 4636.5 0.19 .... 9275.04 7744.9 36.57 124.04 3845.12 -2692.7 4694.2 0.72 [::l EPOCH 49 Forest Oil Corporation Redoubt Unit #2 [MEASURED IHOLE I VERTICAL COORDINATES DOGLEG DEPTH TVD ANGLE AZIMUTH SECTION N (+) or S (-) E (+) or W (-)SEVERITY 9370.88 7822.0 36.49 123.12 3892.64 -2724.2 4751.2 0.58 9466.19 7898.7 36.31 122.70 3940,13 -2755.0 4807.8 0.32 9563.20 7976.0 37,94 124.99 3988.74 -2787.6 4866.3 2,20 9658.90 8051.6 37.78 124.52 4037.00 -2821.1 4925.0 0.34 9751.16 8125.0 36.63 123.65 4083.20 -2852.3 4980.8 1.37 9846.85 8202.1 36.01 123.13 4130.52 -2883.5 5037.5 0.72 9944.35 8280.5 37.08 123.47 4179.05 -2915.4 5095.5 1.11 10036.60 8354.3 36.65 123.55 4225.19 -2946.0 5150.8 0.47 10135.63 8433.2 37.70 126.78 4274.09 -2980.4 5210.6 2.24 10230.37 8507.6 38.75 127.11 4320.94 -3015,7 5269.2 1,13 10323.51 8580.9 37.55 125.12 4367.40 -3049.6 5326.7 1.85 10420.78 8658.3 36.88 123.00 4416,13 -3082.6 5385.6 1.48 10515.76 8734.0 37.43 123.12 4464.21 -3113.8 5442.9 0.58 10610.85 8809.34 37.79 122.79 4512.90 -3145.41 5500.87 0.43 10707.40 8885.39 38.27 123.63 4562.66 -3177.99 5560.32 0.74 10804.17 8961.81 37.42 121.68 4612.64 -3210.04 5619.64 1,52 ,, 10900.96 9039.07 36.66 121.29 4662.35 -3240.49 5677.83 0.82 10994.84 9114,17 37.09 122.59 4710.15 -3270.29 5734.07 0,95 , 11090.08 9189.80 37.78 124.56 4758.38 -3302.31 5791.94 1.45 11185.09 9265.21 37.14 123.51 4806.27 -3334.66 5849.72 0.95 11281.74 9342.53 36.60 124.80 5907.70 4854.26 -3367,21 0.97 11378.31 9419.83 37.05 125,53 5965.59 4901.58 -3400.56 0.65 11475.64 9496.95 38,13 127.41 6024.94 4949,31 -3435,85 1.61 .... 11572.20 9572.90 38.14 127.43 6084.51 4996.66 -3472.08 0.02 11666.89 9647.63 37.65 125,52 6142.65 5043.42 -3506.66 1.34 11764.04 9724.99 36.80 124.55 6201.42 5091.54 -3540.4 1.07 11858.14 9800.55 36.36 123.56 6257.48 5138 -3571.81 0.78 11954.05 9878.30 35.32 122.47 6313.60 5185 -3602.4 1.27 12040.59 9949.00 35.32 122.47 6363.50 5227.2 -3629.3 0.00 , , 12135.88 10026.60 35.61 120.58 6418.70 5274.4 -3658.2 1.19 [::l EPOCH 50 Forest Oil Corporation Redoubt Unit #2 I MEASURED [ HOLEI VERTICAL COORDINATES DOGLEG DEPTH TVD ANGLE AZIMUTH SECTION N (+) or S (-) 'E (+) or W (-) SEVERITY 12231.04 10103.40 36.78 119.52 6474.70 5323 -3686.3 1.39 12326.00 10178.70 38.30 122.08 6532.40 5372.7 -3715.9 2.29 12421.52 10253.10 39.42 127.24 6592.30 5421.9 -3750 3.59 12515.32 10326.00 38.44 127.35 6651.20 -3785.70 5468.80 1.05 12607.21 10398.00 38.51 127.40 6708.30 -3820.40 5514.20 0.08 12704.55 10474.10 38.63 127.03 6768.90 -3857.10 5562.60 0.27 12796.08 10545.40 38.90 127.70 6826.20 -3891.90 5608.10 0.55 12893.72 10621.50 38.69 126.69 6887.30 -3928.90 5656.80 0.68 12989.56 10696.80 37.88 126.58 6946.70 -3964.30 5704.50 0.85 13083.81 10771.70 36.77 127.57 7003.80 -3998.80 5750.10 1.34 13181.67 10849.90 37.18 128.85 7062.60 -4035.20 5796.30 0.89 13276.84 10925.90 36.87 127.47 7119.80 -4070.60 5841.40 0.93 13372.08 11001.50 38.05 129.03 7177.60 -4106.50 5886.90 1.59 13469.13 11077.50 37.90 129.89 7237.80 -4144.40 5933.80 0.57 13562.55 11151.20 37.80 129.69 7295.00 -4181.10 5977.80 0.17 13658.78 11227.30 37.71 129.97 7353.70 -4218.90 6023.10 0.20 13755.59 11303.79 37.90 129.84 7412.83 -4256.95 6068.65 0.22 13851.23 11378.76 38.86 t29.14 7472.04 -4294.71 6114.48 1.10 .... 13947.29 11453.26 39.43 128.67 7532.54 -4322.79 6161.67 0.67 14042.63 11527.75 37.79 129.91 7591.87 -4370.45 6207.72 1.90 , , 14137.10 11602.19 38.22 129.83 7649.83 -4407.74 6252.37 0.46 14233.56 11677.61 38.91 130.61 7709.72 -4446.57 6298.28 0.87 14263.02 11700.60 38.50 130.37 7728.00 -4458.50 6312.20 1.48 i 14372.60 11787.70 36.21 130.59 7794.20 -4501.70 6362.80 2.09 14438.24 11841.00 35.25 129.93 7832.40 -4526.50 6392.10 1.59 14458.64 11857.70 34.59 129.48 78844.00 -4533.90 6401.10 3.47 14515.76 11904.70 34.78 129.22 7876.40 -4554.50 6426.20 0.42 14559.20 11940.50 34.03 127.75 7900.90 -4569.80 6445.40 2.58 14630.12 11999.50 33.67 125.07 7940.40 -4593.20 6477.20 2.17 14718.12 12073.30 32.21 122.90 7988.20 -4620.00 6516.80 2.13 EPOCH 51 .,, Forest Oil Corporation Redoubt Unit #2 I MEASURED I IHOLE VERTICAL COORDINATES DOGLEG DEPTH TVD ANGLE AZIMUTH SECTION N (+) or S (-) E (+) or W (-) SEVERITY 14806.00 12147.50 -4644.49 6556.95 14900.00 12227.45 -4667.08 6601.03 14949.00 12269.47 -4676,85 6624.27 15004.00 12316.84 -4686.20 6650.59 EPOCH 52 ~ Forest Oil Corporation Redoubt Unit #2 BIT RECORD BIT GRADING BIT SERIAL SIZE JETSl I DEPTH'DEPTH FEET BIT AVG AVG AVG PUMP NUMBER NUMBER INCHES MAKE TYPE (in 32rids) IN POOH DRILLED HOURSFTIHR woa RPM PSI 1 LK2070 17.5 STC SASC 3X18, 3X12 143 168 25 I 401 5.7 62.4 742 2 LK0803 18.5 STC MSDSSHC 3X18, 1X12 168 3226 3058 92.2 15.3 48 1735 3 JR7400 12.25 GEO S73HPX 2Xll, 6X12 3226 7832 4606 80.75 98 7.9 49.5 2818 2 3 WI'A X 1~8 4 MG4859 12.25 STC FGSS+C IXII, 2XlS,~X18 7832 8487 655 39 32.4 3t.2 60.1 2905 5 LR0129 t2.25 STC MO5SODGC ~x~l,2x18,~xI5 8487 9029 542 23.5 34.9 32.8 42.9 2890 6 JS3949 8.5 GEO MA985PX 3Xll, 3X12 9029 11250 2221 56.9 17 55.3 2818 5 7 WT A X IH6RO PR 7 JS4028 8.5 GEO MA98SPX 3Xll, 3X12 11250 12234 984 39 50 11.6 57.5 3127 2 2 WFA X I WI' 8 JS4028 8.5 HTC MXR18DD 3X18 12234 12815 581 31 29.5 31.1 48.9 3147 8 8 BT A F 1~4 JD PR 9 LW7171 8.5 STC 25MFDP 3X18 12815 13255 440 26.75 26.5 34.1 41.8 2906 2 3 BT G E ! ER TQ 10 LW7172 8.5 STC 25MFODPS 3X18 13255 13823 568 30.03 26.4 35.1 42.5 3094 2 3 BT G E I ERHRS 11 LK3931 8.5 STC MF25TODPS 3X18 13823 14320 497 23.12 29 39.4 43.4 3213 3 4 BT A E I WT TD 11rr LK3931 8.5 STC MF25TODPS 3X18 14320 14320 CLEAN OUT RUN 0 0 0 3 4 BT A E I WT TD [::1 EPC~H 53 Forest Oil Corporation Redoubt Unit #2 12rr3 MG1206 6.75 STC XR32TDGPS 2X18,1X20 14320 14420 100 14.8 10.7 20.1 47.4 2757 2 2 WT A E ! JD CP 13 1963827 6.75 DPI CORECMM35F 2X18, 1X20 14420 14440 20 4.1 7.8 7.5 49.8 2509 0 0 NO A X I NO PR 13rrl 1963827 6.75 DPI CORECMM35F 2X18,1X20 14440 14475 35 5.6 9.7 7.9 46.7 2444 3 3 WI'A X I BT PR 14 1963828 6.75 DPI CORE CMM35F 2X18, IX20 14475 14537 62 6.1 12.8 6 44 2298 14rrl 1963828 6.75 DPI CORE CMM35F 2X18,1X20 14537 14558 21 4.2 6.8 8.3 44 2396 14rr2 1963828 6.75 DPI CORECMM35F 2X18, tX20 14558 14567 9 4.3 3 7.1 48.7 2583 3 3 W'rA X I BT PR 12rr2 MG1206 6.75 STC XR32TDGPS 2X18,1X20 14567 14594 27 6.3 6.3 25 60 3160 3 6 BT G E I WT CP 15 96003 6.75 DPI CORE GDBC 14594 14621 27 10.7 3 11.4 63.2 1995 6 4 FC A I PR 14rr3 1963828 6.75 DPI CORECMM35F 2Xt8,1X20 14621 14674 53 6.7 13.5 9.7 48.1 2403 3 4 w'rA I CT PR 16 1963878 6.75 DPI CORECMM35F 2X18,1X20 14674 14689 15 4 5 10 64 2355 8 4 RO N I CT PR 17 LY9624 6.75 STC XR20TDGPS 2X18,1X20 14689 14800 111 17.2 12.4 22.1 52.2 2999 6 8 iN'rA E 1~2 BT CP 18 1963862 6.75 DPI CNR55 14800 14844 44 25.9 2.6 11.t 59.3 2291 5 % A I PR 19 1963879 6.75 DPI CMM35F 14844 14898 54 10.1 8.8 8.5 63.8 2401 2 4 Wi'A X I BT PR 20 1963890 6.75 DPI CMM35F 14898 14912 14 3.8 3.7 16.3 34.6 2317 2 4 BT A X I Wi' PR 18rrl 1963862 6.75 DPI CNR55 14912 14934 22 16.5 1.7 13.3 67.9 2440 2 5 RO G X I WT PR 21 1963891 6.75 DPI CMM35F 3X18 14934 14968 34 6.5 7.0 6.1 49.9 2414 3 3 WI'N X I CT PR 13rr2 1963827 6.75 DPI CMM35F 3X18 14968 14978 10 5.8 2.0 9.0 55.7 2570 2 2 WI'A X I BT PR 22 1963901 6.75 DPI CMM35F 3X18 14978 15000 22 6.8 4.5 6.2 75.8 2395 I 2 WT N X I BT PR 22rrl 193901 6.75 DPI CMM35F 3 X 18 15000 15047 47 10.3 6.2 5.3 58.3 2380 1 4 WI'N X I BT PR 23 1963902 6.75 DPI CMM35F 3X18 15047 15060 13 3.8 5.7 6.1 57.4 2472 I 2 WT N X I CT PR 23rrl 1963902 6.75 DPI CMM35F 3Xt8 15060 15088 28 8.4 4.0 7.2 76.9 2456 2 2 CT M X I CT PR 24 G96JE 6.75 HTC EP4983 3X18 15088 15325 237 31.1 9.2 16.4 70.5 2722 3 4 W1 A E I CT TD [:1 EPC 'H 54 Fores~ OB Corpora~io~ R~dou~ Uni~ #2 RIG TIME DISTRIBUTION 84 43 59 26 73 55 17 7 4 17 FOREST OiL CORPORATION REDOUBT UNiT # 2 RIG TIldE D~STRIBUT~ON 55 43 EPOCH 784 68O BIDRILLING BTRIPPtNG EICASING BRIG REPAIR BE-LOGS ~RtG-UP BCOND MUD ~BOP ~BHA i~LEAKOFF BTEST CASG BCEMENTtNG BCOND HOLE ~MtSC FOREST OIL REDOUBT UNIT #2 REPORT FOR D. JONES/M. MURRAY DATE Feb 25, 2001 TIME 4 AM CASING INFORMATION 36" @ 150' SURVEY DATA DALLY WELLSITE REPORT EPOCH DEPTH 750 YESTERDAY 211 24 Hour Footage 539 PRESENT OPERATION= SURVEY @ 750' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 589' 3.00 114 588.88' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 18.5" MSDSSHC LK0803 3x18, lx12 168' 4.74 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 393.8 @ 279 11.2 @ 513 164.3 125.4 ft/hr SURFACE TORQUE 1397 @ 654 28 @ 600 482.8 725.3 amps WEIGHT ON BIT 27 @ 546 0 @ 692 11.9 13,1 Klbs ROTARY RPM 60 @ 510 1 @ 398 60 60 RPM PUMP PRESSURE 1413 @ 705 558 @ 268 1083.0 1384 psi DRILLING MUD REPORT DEPTH: 178' MW 8.8 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) CCI HIGH LOW AVERAGE 7 @ 242 1 @ 257 1.5 TRIP GAS= 1 0 @ 0 0 @ 0 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 1578 @ 242 200 @ 234 309.4 CONNECTION GAS HIGH= 0 @ 715 0 @ 715 0.0 AVG= 0 0 @ 715 0 @ 715 0.0 CURRENT 0 0 @ 715 0 @ 715 0,0 CURRENT BACKGROUND/AVG <1to 2 0 @ 715 0 @ 715 0,0 HYDROCARBON SHOWS NONE - BACKGROUND-TRACE AMTS OF METHANE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY DRILL AND SURVEY; CAME OUT OF HOLE TO CLEAN PITS; TRIP IN AND RESUME DRILL AND SURVEY Epoch Personel On Board= 2 Daily Cost $1743 Report by: GEORGE BAKER FOREST OIL REDOUBT UNIT #2 REPORT FOR DATE Feb 26, 2001 TIME 4 AM CASING INFORMATION 36" @ 150' SURVEY DATA BIT INFORMATION NO. SIZE 2rr2 18,5" TYPE SMITH MSDSSHC DRILLING PARAMETERS RATE Of PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DAILY WELLSITE REPORT DEPTH 1167 YESTERDAY 751 24 Hour Footage 416 DEPTH 801' INCLINATION 2.1 EPOCH PRESENT OPERATION= DRILLING AHEAD AZIMUTH VERTICAL DEPTH 209 800.76' INTERVAL CONDITION SIN JETS IN OUT FOOTAGE HOURS T/B/C LK0803 3x18, lx12 168' 9,4 HIGH LOW AVERAGE CURRENT AVG 273.6 @ 957 14.5 @ 975 120.9 88.8 1204 @ 776 130 @ 896 289.3 154.5 18 @ 855 <1 @ 1043 4,0 10.5 62 @ 1083 60 @ 1021 60 62 1902 @ 1109 530 @ 903 1290.4 1511 REASON PULLED E/hr amps Klbs RPM psi DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TOOLS TO DEPTH: NA VIS PV YP FL Gels CL- SOL SD OIL MBL pH Ca+ CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 2 @ 864 1 @ 1012 1.5 TRIP GAS= 1 CUTTING GAS 0 @ 1111 0 @ 1111 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 589 @ 865 200 @ 1011 CONNECTION GAS HIGH= 0 @ 1111 0 @ 1111 AVG= 0 0 @ 1111 0 @ 1111 CURRENT 0 @ 1111 0 @ 1111 CURRENT BACKGROUND/AVG 1 0 @ 1111 0 @ 1111 METHANE(C-I) 303,2 ETHANE(C-2) 0,0 PROPANE(C-3) 0.0 BUTANE(C-4) 0.0 PENTANE(C-5) 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY DRILL TO 965'-POOH TO CLEAN PITS .MIX AND COND. MUD-RIH AND RESUME DRILLING Epoch Personel On Board= 2 Daily Cost $1743 Report by: GEORGE BAKER FOREST OIL REDOUBT UNIT #2 REPORT FOR M. MURRAY/D. JONES DATE Feb 27, 2001 TIME 4 AM CASING INFORMATION 36"@ 150' SURVEY DATA BIT INFORMATION NO. SIZE 2rr2 18.5" TYPE SMITH MSDSSHC DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DAILY WELLSITE REPORT EPOCH DEPTH 2063 YESTERDAY 1167 24 Hour Footage 896 PRESENT OPERATION= DRILLING AHEAD DEPTH 1858.79 INCLINATION 26.74 INTERVAL S/N JETS IN OUT LK0803 3x18,1x12 168 HIGH LOW 253.7 @ 1316 8.6 707 @ 1699 118 @ 38 @ 1883 <10 @ 60 @ 1167 0 2087 @ 2035 1247 AZIMUTH VERTICAL DEPTH 124.91 1820.13' CONDITION REASON FOOTAGE HOURS T/B/C PULLED 24.8 AVERAGE CURRENT AVG 1465 81.4 29.7 fi/hr 1204 325.5 363.4 amps 1643 14.9 11.3 Klbs 1976 60 60 RPM 1168 1649,3 2041 psi DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS VIS SOL HIGH o @ METHANE(C-I) 321 @ ETHANE(C-2) 0 @ PROPANE(C-3) 0 @ BUTANE(C-4) 0 @ PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL DEPTH: na PV YP SD OIL t LOW AVERAGE 1171 1 @ 2037 1.1 o @ o.o CHROMATOGRAPHY(ppm) 1236 150 @ 1190 231.4 o @ o.o o @ o.o o @ o.o o @ o.o NONE- ONLY TRACE AMTS OF METHANE LITHOLOGY/REMARKS FL Gels CL- MBL pH Ca+ CCI GAS TRIP GAS= WIPER GAS= SURVEY= 0 CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 1 DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY DRILL AND SURVEY Epoch Personel On Board= 2 Daily Cost $1743 Report by: GEORGE BAKER FOREST OIL REDOUBT UNIT #2 REPORT FOR M. MURRAY/D. JONES DATE Feb 28, 2001 TIME 4 AM DAILY WELLSITE REPORT EPOCH DEPTH 2941 YESTERDAY 2063 24 Hour Footage 878 PRESENT OPERATION= DRILLING AHEAD CASING INFORMATION 36"@ 150' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2523.87' 37.88 124.22 2372.5' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2rr 18.5 SMITH MSDSSHC LK0803 3x18,1x12 168 47.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 190.6 @ 2540 7.4 @ 2799 63,3 91.3 ft/hr SURFACE TORQUE 1510 @ 2470 2 @ 2131 563.2 1026.7 amps VVEIGHT ON BIT 45 @ 2823 1 @ 2107 22,8 18,8 Klbs ROTARY RPM 60 @ 2093 0 @ 2700 60 60 RPM PUMP PRESSURE 2818 @ 2894 1420 @ 2783 2188.5 2695 psi DRILLING MUD REPORT DEPTH: 1980 VIS 77 PV 15 YP 33 FL 18 Gels 23/26/28 CL- 700 SOL 6,5 SD TR OIL 0 MBL pH 8.8 Ca+ 40 CCI MW 9.2 FC 2/ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 4 @ 2891 1 @ 2751 1.6 TRIP GAS= CUTTING GAS 0 @ 0 @ 0,0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-I) 895 @ 2891 190 @ 2751 305,1 CONNECTION GAS HIGH= ETHANE(C-2) 0 @ 2903 0 @ 2903 0.0 AVG= 0 PROPANE(C-3) 0 @ 2903 0 @ 2903 0.0 CURRENT 0 BUTANE(C-4), 0 @ 2903 0 @ 2903 0.0 CURRENT BACKGROUND/AVG 3 PENTANE(C-5) 0 @ 2903 0 @ 2903 0.0 HYDROCARBON SHOWS NONE BACKGROUND GAS HAS SLIGHTLY INCREASED INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY ROTATE AND SLIDE Epoch Personel On Board= 2 Daily Cost $1743 Report by: GEORGE BAKER FOREST OIL REDOUBT UNIT #2 REPORT FOR M. MURRAY/D. JONES DATE Mar 06, 2001 TIME 4 AM DALLY VVELLSITE REPORT EPOCH DEPTH 4087 YESTERDAY 3226 24 Hour Footage 861 PRESENT OPERATION= DRILLING AHEAD CASING INFORMATION 36" @ 150 13.375" @ 3212' DEPTH SURVEY DATA BIT INFORMATION NO. SIZE TYPE 3 12.25" GEODIA S73HPX DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE ,, DRILLING MUD REPORT MW 9.O FC MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS 3959' INCLINATION AZIMUTH VERTICAL DEPTH 39.5 124.93 3512.0 SIN JETS JR7400 2x11,6x12 HIGH 440.6 @ 3342 1505 @ 3880 39 @ 354O 66 @ 3924 2921 @ 4016 ViS PV SOL SD , METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C.5) ,,, HYDROCARBON SHOWS INTERVAL ,,. INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 3226 11 LOW AVERAGE CURRENT AVG 2.8 @ 3910 120.6 120.6 ftJhr 0 @ 3944 578.2 739.9 amps <1 @ 3480 9.0 2.1 Klbs 0 @ 3994 60 60 RPM 9O5 @ 3247 2422.6 2680 psi ,. DEPTH: 3228 YP FL Gels CL- OIL MBL pH Ca+ CCI HIGH LOW AVERAGE 165 @ 3603 1 @ 3227 35.9 TRIP GAS= 0 @ 0 @ 0.0 WIPER GAS= 10 CHROMATOGRAPHY(ppi) SURVEY= 32530 @ 3603 290 @ 3227 7134,3 CONNECTION GAS HIGH= 0 @ 0 @ 0.0 AVG= 0 0 @ 0 @ 0,0 CURRENT 0 @ 0 @ 0.0 CURRENT BACKGROUND/,AVG 20 o @ o @ o.o NONE- MENTHANE COAL GAS ONLY LITHOLOGY/REMARKS GAS DESCRIPTION ,,, LITHOLOGY COAL GAS SHOW AT 3590'MD/3221'TVD - INTERPRETED EQUIVALENT TO 3540'MD/3218'TVD ON RU#1 PRESENT LITHOLOGY HAVE DRILLED NUMEROUS COALS ,, DALLY ACTIVITY RUN IN HOLE W/NB#3-DRILL CMT-TEST STAGE COLLAR-DRILL TO 2216'-TEST CSG-DRILL OUT TO 3246' AND PERFORM L.O.T- SUMMARY RESUME DRILLING FORMATION. SHORT TRIP AT 4031 '-RESUME DRILLING Epoch Personel On Board= 2 Daily Cost $1743 Report by: GEORGE BAKER FOREST OIL REDOUBT UNIT #2 REPORT FOR D. JONESWI. MURRAY DATE Mar 07, 2001 TIME 02:15:26 CASING INFORMATION 13.375" @ 3212' SURVEY DATA BIT INFORMATION NO. SIZE 3 12,25" TYPE GEODIA S73HPX DAILY WELLSITE REPORT EPOCH DEPTH 5670 YESTERDAY 4087 24 Hour Footage 1583 DEPTH 5490 INCLINATION 37.23 INTERVAL SIN JETS IN OUT J R7400 2xl 1,6xl 2 3226 PRESENT OPERATION= DRILLING AHEAD AZIMUTH VERTICAL DEPTH 124.68 4712.53' FOOTAGE HOURS 27.6 CONDITION REASON T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE VVEIGHT ON BIT ROTARY RPM PUMP PRESSURE HIGH LOW 421.9 @ 4798 7.3 @ 4567 1496 @ 5372 0 @ 4796 48 @ 5277 <1 @ 5345 61 @ 4941 0 @ 4796 3163 @ 4644 1008 @ 4796 AVERAGE CURRENT AVG 119.4 '114.3 ft/hr 745.7 1050,8 amps 4.3 7.2 Klbs 60 60 RPM 2868,0 2957 psi DRILLING MUD REPORT MW 9.1 VIS FC 2/ SOL MWD SUMMARY INTERVAL TO TOOLS ,, GAS SUMMARY(units) DITCH GAS CU'FI'ING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) DEPTH: 4031 40 PV 7 YP 11 FL 5 SD ,25 OIL 0 MBL HIGH LOW AVERAGE 147 @ 4147 1 @ 5517 32.5 o @ o @ o.o CHROMATOGRAPHY(ppm) 29804 @ 4147 340 @ 5517 6227.1 14 @ 4516 2 @ 4519 0.0 o @ o @ o.o o @ o @ o.o o @ o @ o,o Gels 5/25/40 CL- 400 pH 11 Ca+ 40 CCI TRIP GAS= WIPER GAS= 20 SURVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 10 HYDROCARBON SHOWS NONE- COAL GAS ONLY- GAS CORRELATING VERY WELL W/RU#! INTERVAL LITHOLOGY/REMARKS GAS LITHOLOGY PRESENT LITHOLOGY PRESENTLY IN A CLAYSTONE SECTION DAILY ACTIVITY SUMMARY DRILLING AHEAD-SHORT TRIP AT 4702'- TRIP IN AND RESUME DRILLING DESCRIPTION Epoch Personel On Board= 2 Daily Cost $1743 Report by: GEORGE BAKER FOREST OIL CORP. REDOUBT UNIT #2 REPORT FOR D. JONES/M. MURRAY DATE Mar 09, 200.1 TIME 4AM DAILY WELLSITE REPORT EPOCH DEPTH 7160 YESTERDAY 6335 24 Hour Footage 825 PRESENT OPERATION= SHORT TRIP (AT SHOE) CASING INFORMATION 13.375"@ 3212' DEPTH SURVEY DATA 6992.99' INCLINATION AZIMUTH VERTICAL DEPTH 35.97 125.55 5909.0' BIT INFORMATION NO. SIZE TYPE SIN 3 12.25" GEODIAS73HPX JR7400 DRILLING PARAMETERS RATE OF PENETRATION 255.4 SURFACE TORQUE 1731 WEIGHT ON BIT 54 ROTARY RPM 82 PUMP PRESSURE 3240 INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2xl 1,6x12 3226 52.28 HIGH LOW AVERAGE CURRENT AVG @ 6874 4.2 @ 6791 84,1 84.2 fi/hr @ 6435 116 @ 6972 902,0 686.9 amps @ 6873 <1 @ 6887 8.6 12,3 Klbs @ 6962 27 @ 6680 60 82 RPM @ 6385 1613 @ 6860 2845,7 2966 psi DRILLING MUD REPORT MW 9.4 VIS 43 PV FC 2/ SOL 7.0 SD DEPTH: 7159' 11 YP 16 FL 9.1 Gels 9/12/16 CL~ 450 .125 OIL tr MBL pH 8,3 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I-I'ING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH LOW AVERAGE 297 @ 6902 7 @ 6974 48,4 TRIP GAS= 0 @ 0 @ 0,0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 59480 @ 6902 1592 @ 6974 9681,8 CONNECTION GAS HIGH= 60 @ 6902 1 @ 7070 5.9 AVG= 0 0 @ 0 @ 0.0 CURRENT 0 @ 0 @ 0,0 CURRENT BACKGROUND/AVG 55 o @ o @ o.o HYDROCARBON SHOWS INTERVAL COAL GAS SHOWS- POSSIBLE SAND GAS SHOWS 7072'-7160'-119 TO 120 UNITS-STILL RECEIVING 100+ UNITS BEFORE WIPER TRIP LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY DRILL TO 7160'- SHORT TRIP TO SHOE Epoch Personel On Board= 2 Daily Cost $1743 Report by: GEORGE BAKER FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR D. JONES/M. MURRAY DATE Mar 10, 2001 TIME 4 AM CASING INFORMATION 13.375"@ 3212' DALLY WELLSITE REPORT EPOCH DEPTH 7585 YESTERDAY 7160 24 Hour Footage 425 PRESENT OPERATION= RESUME DRILLING DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7447' 36,61 125.32 6298.10' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25" GEODIAS73H PX JR7400 2xl 1,6x12 3226 65,1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 219,8 @ 7231 2.3 @ 7263 55.5 64.7 fi/hr SURFACE TORQUE 1805 @ 7272 27 @ 7418 760.5 977.0 amps WEIGHT ON BIT 57 @ 7432 <1 @ 7245 13.8 11.0 Klbs ROTARY RPM 82 @ 7272 0 @ 7419 80 75 RPM PUMP PRESSURE 3303 @ 7227 1804 @ 7505 2849.3 2976 psi DRILLING MUD REPORT MW 9,4 VIS 43 PV FC 2/ SOL 7,0 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 223 @ 7522 7 @ 7466 65.5 TRIP GAS= CU'I-I'ING GAS 0 @ 0 @ 0.0 WIPER GAS= 85 CHROMATOGRAPHY(ppm) SURVEY= METHANE(C-I) 57050 @ 7522 1646 @ 7260 15928.9 CONNECTION GAS HIGH= ETHANE(C-2) 66 @ 7496 1 @ 7242 18.4 AVG= 0 PROPANE(C-3) 25 @ 7544 1 @ 7575 3.4 CURRENT BUTANE(C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 40 PENTANE(C-5) 0 @ 0 @ 0.0 DEPTH: 7159' 11 YP 16 FL 9,1 Gels 9/12/16 CL- 450 ,125 OIL tr MBL pH 8,3 Ca+ 20 CCI HYDROCARBON SHOWS RECEIVING SAND GAS SHOWS WITH COAL GAS SHOWS BELOW 7080'-MAX, GAS 223u @ 7522'- NO OIL INDICATORS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND COALS INTERBEDDED WITH SANDSTONE SECTIONS PRESENT LITHOLOGY 50% SAND 30% COAL AND CARBONACEOUS SHALE 20% CLAYSTONE DAILY ACTIVITY SUMMARY DRILL TO 7580'-SHORT TRIP-TRIP IN AND RESUME DRILLING Epoch Personel On Board= 4 Daily Cost $2303 Report by: GEORGE BAKER FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR D. JONES/M. MURRAY DATE 3/11/2001, TIME 00:00:00 DALLY WELLSITE REPORT EPOCH DEPTH 7832 YESTERDAY 7585 24 Hour Footage 247 PRESENT OPERATION= TRIP OPERATIONS CASING INFORMATION 13.375"@ 3212' DEPTH SURVEY DATA 7757.79' INCLINATION AZIMUTH VERTICAL DEPTH 35.99 125.64 3790.8' BIT INFORMATION NO. SIZE TYPE 3 12.25" GEODIAS73HPX 4 12.25" SMITH FGSS+C DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.45 VIS FC 8.6 SOL 44 7.0 SIN JR7400 MG4859 HIGH 168.9 1523 76(SLIDE) 81 3188 JETS INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 3226 7832 4606 74.08 7832 LOW AVERAGE CURRENT AVG 7668 2.4 @ 7832 46.4 ftJhr 7675 268 @ 7585 986,6 amps 7800 3 @ 7657 12.9 Klbs 7695 0(SLIDE) @ 7819 70.9 RPM 7744 2104 @ 7705 2997.2 psi DEPTH: 7832~ PV 13 YP 18 FL 8.6 Gels 10/13/17 CL- 350 SD .125 OIL tr MBL pH 8.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS 198 CUTTING GAS 0 METHANE(C-I) 43481 ETHANE(C-2) 126 PROPANE(C-3) 27 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL H IG H LOW AVERAGE @ 7811 3 @ 7770 37.8 TRIP GAS= @ 0 @ 0.0 WIPER GAS= 148(7580) CHROMATOGRAPHY(ppm) SURVEY= @ 7811 702 @ 7608 7791.4 CONNECTION GAS HIGH= @ 7599 1 @ 7829 9.5 AVG= 0 @ 7809 1 @ 7828 1.4 CURRENT @ 0 @ 0.0 CURRENT BACKGROUND/AVG 10 @ o @ o,o GAS SHOW AT 7800' TO 7820' FROM SANDSTONE INTERVAL -MAX 198 UNITS- NO OIL INDICATORS LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY DRILLING THRU CLAYSTONE INTERVAL- DRILLED SANDSTONE AT 7800-28' PRESENT LITHOLOGY 60% SAND, 30% CLAYSTONE, 10% CARBONACEOUS SHALE DAILY ACTIVITY SUMMARY DRILL TO 7832'- CIRCULATE BO'I-I'OMS UP-POOH FOR NEW BIT AND BHA-TEST BOP'S-MAKE UP BHA Epoch Personel On Board= 4 Daily Cost $2303 Report by: GEORGE BAKER FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR D. JONES/M. MURRAY DATE Mar 12, 2001 TIME 4AM CASING INFORMATION 13.375" @ 3212' DALLY WELLSITE REPORT DEPTH 8168 YESTERDAY 7832 24 Hour Footage 336 EPOCH PRESENT OPERATION= DRILLING SURVEY DATA DEPTH 8044.35' INCLINATION 37.3 AZIMUTH 124.8 VERTICAL DEPTH 6758.20' BIT INFORMATION NO. SIZE 4 12.25" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.25 FC 2/ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I-I'ING GAS TYPE SMITH FGSS+C ViS 41 PV SOL 6 SD METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) S/N MG4859 150.7 1506 76 71 3183 JETS 1x11,2x15,1x18 HIGH @ 7909 @ 8039 @ 7800 @ 7923 @ 7854 DEPTH: 8143' 13 YP .125 INTERVAL IN OUT 7832 LOW 1.9 @ 7832 123 @ 8093 1 @ 7833 0 @ 8057 2O90 @ 8O73 15 FL OIL tr MBL 8.4 363 0 67444 108 37 0 0 HIGH LOW AVE RAG E @ 8139 1 @ 7940 48.2 @ 8154 0 @ 8154 0.0 CHROMATOGRAPHY(ppi) @ 8139 209 (~ 7940 10431.1 @ 8139 1 @ 8014 11.7 @ 8139 1 @ 7881 4.2 @ o @ o,o @ o @ o.o FOOTAGE HOURS 15.3 CONDITION REASON T/B/C PULLED AVERAGE CURRENT AVG 38.6 10.7 ~hr 682.7 418.1 amps 31.2 28.4 Klbs 64 54 RPM 2912.9 2756 psi Gels 8/11/17 CL- 300 pH 8.8 Ca+ 40 CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 55 HYDROCARBON SHOWS INTERVAL MENTHANE COAL GAS ONLY- MAXIMUM 363 UNITS AT 8139' LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY JUST DRILLED A THICK COALEY SECTION FROM 8110'TO8145'-GAS BACKGROUND STILL HIGH AT55UNITS;RETURN TO CLAYSTONE SECTION. 30% COAL, 50% TUFFACEOUS CLAYSTONE, 20% SAND DAILY ACTIVITY SUMMARY RUN IN HOLE W/NEW BHA- WASH AND REAM F/7736-7832'-NO FILL. RESUME DRILLING Epoch Personel On Board= 4 Daily Cost $2303 Report by: GEORGE BAKER FOREST OIL CORP. REDOUBT UNIT #2 REPORT FOR M. MURRAY~D. JONES DATE Mar 14, 2001 TIME 4AM CASING INFORMATION 13,375"@ 3212' SURVEY DATA BIT INFORMATION NO. SIZE 4 12.25" 5 12.25" DALLY WELLSITE REPORT EPOCH DEPTH 8487 YESTERDAY 8374 24 Hour Footage 113 PRESENT OPERATION= TRIP IN HOLE DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8412.5' 36.13 123.08 7051.85' INTERVAL CONDITION REASON TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED SMITH FGSS+C MG4859 lx11,2x15,1x18 7832 8478 655 33.61 SMITH MO5SODGC LR0129 lx11,2x18,1x15 8478 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 FO 2/ MWD SUMMARY INTERVAL TO TOOLS HIGH LOW AVERAGE CURRENT AVG 93,4 @ 8404 4.2 @ 8427 32.3 6.2 1284 @ 8359 30 @ 8453 819,6 657.0 76 @ 8454 11 @ 8394 30,2 15.8 70 @ 8469 0 @ 8461 64 64 3140 @ 8416 2431 @ 8452 2966,4 2591 DEPTH: 8487 VIS 45 PV 13 YP 19 FL 8,2 Gels 10/13/18 CL- 300 SOL 6 SD .125 OIL tr MBL pH 8.4 Ca+ 40 fi/hr amps Klbs RPM psi CCI GAS SUMMARY(units) DITCH GAS CU'FI'ING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C.5) HYDROCARBON SHOWS INTERVAL HIGH LOW AVERAGE 266 @ 8409 28 @ 8468 80.7 TRIP GAS= 0 @ 0 @ 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 52572 @ 8409 5625 @ 8468 16177.9 CONNECTION GAS HIGH= 79 @ 8409 8 @ 8426 22,4 Ave= 0 23 @ 8408 1 @ 8445 5.4 CURRENT 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVe 40 o @ o @ o.o COAL GAS SHOWS AT 8394'-266u MAX AND AT 8470'-170u MAX LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE SECTION WITH COALS AND SANDS PRESENT LITHOLOGY 40% TUFFACEOUS CLAYSTONE, 30% COAL, 30% SAND DALLY ACTIVITY DRILL TO 8487', CIRCULATE BO'I-rOMS UP, MONITOR WELL- TRIP OUT-MONITOR WELL AT SHOE; PULL OUT OF HOLE; SUMMARY CHANGE OUT BIT; RUN IN HOLE. Epoch Personel On Board= 4 Daily Cost $2303 Report by: GEORGE BAKER FOREST OIL COMPANY REDOUBT UNIT #2 REPORT FOR Mike Murray DATE Mar 17, 2001 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 9029 YESTERDAY 9029 24 Hour Footage 0 EPOCH LOGO PRESENT OPERATION= POOH CASING INFORMATION 13.375"@ 3212' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8957.30 35.38 123.09 7490.10 SURVEY DATA BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 5 12.25" SMITH MO5SODGC LR0129 lxll,2x18, lx15 8478 9029 551 24.2 CONDITION REASON T/B/C PULLED TD DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC 'MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS VIS PV SOL SD HIGH LOW AVERAGE o @ o o @ o o o @ o o @ o o o @ o o @ o o o @ o o @ o o o @ o o @ o o DEPTH: HIGH LOW AVERAGE o @ o o @ o o o @ o o @ o o CHROMATOGRAPHY(ppm) CURRENT AVG 0 0 0 0 0 METHANE(C-I) 0 @ 0 0 @ 0 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS YP FL Gels CL- OIL MBL pH Ca+ fi/hr amps Klbs RPM psi CCI TRIP GAS= 27O WIPER GAS= 150 SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AV'G GAS DESCRIPTION LITHOLOGY Tuffaceous Claystone interbedded with thick sand/conglomerate and coals PRESENT LITHOLOGY 60% Tuffaceous Claystone, 30% Sand, 10% Tuffaceous Siltstone II IDAILY ACTIVITY Run wire line log. Rig down Schlumberger. Pick up BHA. RIH to shoe, Fill pipe. Cut and Slip Ddlling line. Service top SUMMARY drive. RIH and Circulate, Pump sweep and condition mud. POOH. Epoch Personel On Board= 1 Daily Cost $2108 Report by: Christian Ornt FOREST OIL COMPANY REDOUBT UNIT #2 REPORT FOR Mike Murray DATE Mar 18, 2001 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 9029 YESTERDAY 9029 24 Hour Footage 0 CASING INFORMATION 13.375" @ 3212' DEPTH 8957.30 PRESENT OPERATION= Running in hole with casing INCLINATION 35.38 AZIMUTH VERTICAL DEPTH 123.09 7490.10 SURVEY DATA BIT INFORMATION NO. SIZE TYPE SIN 5 12.25" SMITH MO5SODGC LR0129 JETS 1x11,2x18, lx15 INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 8478 9029 551 24.2 TD DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS VIS PV SOL SD HIGH LOW @ o o @ @ o o @ ~ O 0 I ~ GOO @ GOO@ DEPTH: HIGH LOW AVERAGE o @ o o @ o o o @ o o @ o o CHROMATOGRAPHY(ppm) METHANE(C-I) 0 @ 0 0. @ 0 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 PENTANE(C-5) 0 @ 0 0 @ 0 . 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS AVERAGE CURRENT AVG 0 0 0 fi/hr 0 0 0 amps 0 0 0 Klbs 0 0 0 RPM 0 0 0 psi YP FL Gels CL- OIL MBL pH Ca+ LITHOLOGY Tuffaceous Claystone interbedded with thick sand/conglomerate and coals PRESENT LITHOLOGY 60% Tuffaceous Claystone, 30% Sand, 10% Tuffaceous Siltstone CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUN D/AVG GAS DESCRIPTION Epoch Personel On Board= 1 Report by: Christian Ornt Daily Cost $2108 FOREST OIL COMPANY REDOUBT UNIT #2 REPORT FOR Mike Murray DATE Mar 19, 2001 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 9029 YESTERDAY 9029 24 Hour Footage 0 EPOCH LOGO PRESENT OPERATION= Clean out stack and pits CASING INFORMATION 13.375" @ 3212' I DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8957.30 35.38 123.09 7490.10 SURVEY DATA BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 5 12.25" SMITH MO5SODGC LR0129 1x11,2x18, lx15 8478 9029 551 24.2 CONDITION REASON T/B/C PULLED TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 SURFACE TORQUE 0 @ 0 0 @ 0 0 0 'WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 ROTARYRPM 0 @ 0 0 @ 0 0 0 PUMP PRESSURE 0 @ 0 0 @ 0 0 0 IIIII IIII DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH LOW AVERAGE o @ o o @ o, o o @ o o @ o o CHROMATOGRAPHY(ppm) METHANE(C-I) 0 @ 0 0 @ 0 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS CCI ft/hr amps Klbs RPM psi TRIP GAS= 320 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION II II LITHOLOGY Tuffaceous Claystone interbedded with thick sand/conglomerate and coals PRESENT LITHOLOGY 60% Tuffaceous Claystone, 30% Sand, 10% Tuffaceous Siltstone Epoch Personel On Board= 1 Daily Cost $2108 Report by: Christian Omt FOREST OIL COMPANY REDOUBT UNIT #2 REPORT FOR Don Jones DATE Mar 20, 2001 TIME 00:00:00 DAILY WELLSITE REPORT DEPTH 9029 YESTERDAY 9029 24 Hour Footage 0 EPOCH LOGO PRESENT OPERATION= Test BOP CASING INFORMATION 13.375" @ 3212' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8957.30 35.38 123.09 7490.10 SURVEY DATA BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 5 12.25" SMITH MO5SODGC LR0129 1xll.2x18, lx15 8478 9029 551 24.2 CONDITION REASON T/B/C PULLED TD DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 0 @ 0 0 @ '0 0 SURFACE TORQUE 0 @ 0 0 @ 0 0 WEIGHT ON BIT 0 @ 0 0 @ 0 0 ROTARYRPM 0 @ 0 0 @ 0 0 PUMP PRESSURE 0 @ 0 0 @ 0 0 DRILLING MUD REPORT DEPTH: II CURRENT AVG 0 ft/hr 0 amps 0 Klbs 0 RPM 0 psi MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ TO MWD SUMMARY INTERVAL TOOLS HIGH LOW AVERAGE o @ o o @ o o o @ o o @ o o CHROMATOGRAPHY(ppm) GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) 0 @ 0 0 @ 0 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS CCI TRIP' GAS= 320 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION LITHOLOGY Tuffaceous Claystone interbedded with thick sand/conglomerate and coals o PRESENT LITHOLOGY 60 Yo Tuffaceous Claystone, 30% Sand, 10% Tuffaceous Siltstone II FOREST OIL CORP. REDOUBT UNIT #2 REPORT FOR D.JONES/M.MURRAY DATE Mar 22, 2001 TIME 4AM CASING INFORMATION 9.625" @ 9011' DALLY WELLSITE REPORT EPOCH DEPTH 9832 YESTERDAY 9029 24 Hour Footage 803 PRESENT OPERATION= DRILLING AHEAD DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9751.16' 36,63 123.65 8125.04' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 8,5" GEODIA MA985PX JS3949 9029 14.7 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,0 FC MWD SUMMARY INTERVAL TO TOOLS HIGH LOW AVERAGE CURRENT AVG 457.0 @ 9032 6.6 @ 9750 80.6 39.9 fi/hr 1146 @ 9291 0 @ 9243 672.2 855.2 amps 38 @ 9247 <1 @ 9159 11.2 4,8 Klbs 64 @ 9291 0 @ 9244 54 54 RPM 3301 @ 9399 1691 @ 9625 3120.0 3078 psi DEPTH: 9029' VIS PV YP FL Gels SOL SD OIL MBL pH CL- Ca+ CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 328 @ 9218 8 @ 9036 49.3 TRIP GAS= CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-I) 65081 @ 9218 936 @ 9036 8542,4 CONNECTION GAS HIGH= ETHANE(C-2) 77 @ 9695 1 @ 9190 17,3 AVG= 0 PROPANE(C-3) 59 @ 9044 1 @ 9655 4.3 CURRENT BUTANE(C-4) 286 @ 9044 1 @ 9505 13,1 CURRENT BACKGROUND/AVG 22 PENTANE(C-5) 301 @ 9043 1 @ 9510 18,1 HYDROCARBON SHOWS COAL GAS SHOWS-ABOVE HEAVY CHROM VALUES FROM OIL BASE MUD SYSTEM INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENTLY DRILLING THROUGHT TUFFACEOUS CLAYSTONE SECTION WITH COALS PRESENT LITHOLOGY 80% TUFFACEOUS CLAYSTONE, 10% TUFFACEOUS SILTSTONE; 10% SAND DAILY ACTIVITY SUMMARY TEST CASING AND PERFORM L.O.T. RESUME DRILLING Epoch Personel On Board= 4 Daily Cost $2363 Report by: GEORGE BAKER FOREST OIL CORP. REDOUBT UNIT #2 REPORT FOR D.JONES/M. MURRAY DATE Mar 23, 2001 TIME 4AM CASING INFORMATION 9.625" ~ 9011' SURVEY DATA BIT INFORMATION NO, SIZE TYPE 6 8.5" GEODIA MA985PX DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.95 VIS 80 FC SOL 9.39 DAILY WELLSITE REPORT EPOCH DEPTH 10381 YESTERDAY 9832 24 Hour Footage 549 DEPTH 1023O.37' INCLINATION 38.75 PV SD S/N JETS JS3949 3xl 1,3x12 HIGH 140.8 @ 10177 4.9 1 O48 @ 1 O342 7 49 @ 9850 <1 64 @ 1O174 0 7521 @ 1O254 0 DEPTH: 9751' 26 YP 18 OIL 71.5 INTERVAL IN 9029' OUT LOW @ 9870 @ 9860 @ 1OO23 @ 10081 @ 1o247 FL 10.3 MBL PRESENT OPERATION= DRILLING AHEAD AZIMUTH VERTICAL DEPTH 127.11 8507.6' FOOTAGE CONDITION REASON HOURS T/B/C PULLED 30,7 AVERAGE 44.7 646.9 18.3 64 1558,5 Gels pH 10/14/19 CURRENT AVG 11.7 fi/hr 1009.7 amps 17.3 Klbs 64 RPM 3092 psi CL- 29500 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 156 @ 9839 10 @ 10299 33.5 CUTTING GAS 0 @ 10350 0 @ 10350 0,0 CHROMATOGRAPHY(ppm) 27791 9839 1277 @ 10299 4942,7 228 10217 5 @ 10300 30,8 57 10217 1 @ 10300 8,0 41 9872 1 @ 10312 3,5 0 10350 0 @ 10350 0,0 , , TRIP GAS= WIPER GAS= 195u SURVEY: CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 20 METHANE(C-I) @ ETHANE(C-2) @ PROPANE(C-3) @ BUTANE(C-4) @ PENTANE(C-5) @ HYDROCARBON SHOWS COAL GAS SHOWS- CHROM-C-4-C-5 FROM OIL BASE MUD SYSTEM INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION TUFFACEOUS SlLTSTONES INTERBEDDED WITH THIN COALS,SANDS AND CLAYSTONES LITHOLOGY CLAYSTONES PRESENT LITHOLOGY 50% TUFFACEOUS SILTSTONE, 30% SAND, 20% TUFFACEOUS CLAYSTONES DAILY ACTIVITY SUMMARY DRILL TO 10006'; SHORT TRIP; PERFORM ANNULUS INJECTIVITY TESTS; RIH AND RESUME DRILLING Epoch Personel On Board= 4 Daily Cost $2363 Report by: GEORGE BAKER FOREST OIL CORP. REDOUBT UNIT #2 REPORT FOR D. JONES/M. MURRAY DATE Mar 24, 2001 TIME 4AM CASING INFORMATION 9.625"@ 9011' DALLY WELLSITE REPORT EPOCH DEPTH 10847 YESTERDAY 10381 24 Hour Footage 466 PRESENT OPERATION= DRILLING AHEAD SURVEY DATA DEPTH 10610.85' INCLINATION 37.79 AZIMUTH 122.79 VERTICAL DEPTH 8809.34' BIT INFORMATION NO. SIZE 6 8.5" TYPE GEODIA MA985PX DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE INTERVAL SIN JETS IN OUT JS3949 3xl 1,3x12 9029' HIGH LOW 135.1 @ 10441 8.4 1215 @ 10772 222 @ 58 @ 10622 <1 64 @ 10662 0 3534 @ 10797 2143 FOOTAGE HOURS 44.5 CONDITION REASON T/B/C PULLED AVERAGE CURRENTAVG 10771 42.8 39.7 ~hr 10614 760.5 935.6 amps 10549 21.3 24,1 Klbs 10614 64 64 RPM 10676 3253.3 3448 psi DRILLING MUD REPORT MW 9.0 VIS FC SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) 65 9.23 DEPTH: 10255' PV 18 YP 15 FL SD OIL 72 MBL 10.5 HIGH LOW AVERAGE 15o @ 10573 11 @ 10537 39.2 o @ o @ o.o CHROMATOGRAPHY(ppm) 28870 @ 10573 1444 @ 10537 5952,9 110 @ 10471 8 @ 10537 28.1 36 @ 10471 1 @ 10684 8.7 24 @ 10471 1 @ 10608 1,4 0 @ 10800 0 @ 10800 0.0 Gels pH 8/14/14 CL- Ca+ 33000 CCI TRIP GAS= WIPER GAS= 132 S U RVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 25 HYDROCARBON SHOWS COAL GAS SHOWS- HEAVIES REFLECT OIL BASE MUD SYSTEM INTERVAL LITHOLOGY/REMARKS GAS ,,, LITHOLOGY TUFFACEOUS SILTSTONE WITH THIN COALS PRESENT LITHOLOGY 50% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS CLAYSTONE, 20% SAND, 10% COAL DESCRIPTION DALLY ACTIVITY SUMMARY DRILL TO 10548'- SHORT TRIP TO SHOE- RIH AND RESUME DRILLING Epoch Personel On Board= 4 Daily Cost $2363 Report by: GEORGE BAKER FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR D. JONES/M. MURRAY DATE Mar 26, 2001 TIME 4AM CASING INFORMATION 9.625"@ 9011' DAILY WELLSITE REPORT DEPTH 114O4 YESTERDAY 11205 24 Hour Footage 199 EPOCH PRESENT OPERATION= DRILLING AHEAD SURVEY Data BIT INFORMATION NO, SIZE 7 8.5" TYPE GEODIA MA982PX DRILLING PARAMETERS RATE Of PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DEPTH 11185.09' INCLINATION 37.14 INTERVAL SIN JETS IN OUT JS40284x15 4x15 11249' HIGH LOW 182.6 @ 11346 8.8 1129 @ 11352 124 @ 61 @ 11331 <1 64 @ 11260 0 @ 3476 @ 11362 2409 AZIMUTH VERTICAL DEPTH 123.51 9265.2 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 3,48 AVERAGE CURRENT AVG 58.5 17.8 fi/hr 718,9 235,8 amps 16.1 0.4 Klbs 49.3 0 RPM 3198.9 2871 psi 11223 11307 11393 11254 11254 DRILLING MUD REPORT MW 9.2 VIS FC SOL MWD SUMMARY INTERVAL TO TOOLS DEPTH; 11194' 100 PV 15 YP 30 FL 10,71 SD OIL 72 MBL Gels 11/16/18 CL- pH Ca+ 33000 CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 113 @ 11238 13 @ 11320 32.0 CU'I-I'ING GAS 0 @ 0 @ 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 20375 @ 11238 2227 @ 11320 5676.2 ETHANE(C-2) 220 @ 11256 9 @ 11320 37.3 PROPANE(C-3) 55 @ 11256 4 @ 11391 11.2 BUTANE(C-4) 54 @ 11256 5 @ 11331 21.5 PENTAN E(C-5) 0 @ 11393 0 @ 11393 0.0 , , , HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS TRIP GAS= 107 WIPER GAS= S U RVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 20 DESCRIPTION LITHOLOGY TUFFACEOUS SANDSTONES AND CLAYSTONES WITH THIN COALS PRESENT LITHOLOGY 50% COAL, 40% TUFFACEOUS CLAYSTONES, 10% TUFFACEOUS SILTSTONES DAILY ACTIVITY SUMMARY DRILL TO 11249'-CIRC BTMS UP-TRIP FOR NEW BIT-RIH AND RESUME DRILLING Epoch Personel On Board= 4 Daily Cost $2363 Report by: GEORGE BAKER FOREST OIL REDOUBT UNIT #2 REPORT FOR M. MURRAY/D.JONES DATE Mar 29, 2001 TIME 4AM DAILY WELLSITE REPORT EPOCH DEPTH 12328 YESTERDAY 12234 24 Hour Footage 94 PRESENT OPERATION= DRILLING AHEAD CASING INFORMATION 9.625" @ 9011' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12135.88 35.61 120.58 10026.02' BIT INFORMATION INTERVAL CONDITION NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C 7 8.5 GEODIA MA985PX JS3949 11249 12234' 985 ' 29.823 8 8,5 HTC MX-R18DD JS4028 3x18 12234' 6.67 ,, DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 80.7 @ 12251 6,7 @ 12289 23.3 23.1 SURFACE TORQUE 1167 @ 12287 185 @ 12250 558.6 330.3 WEIGHT ON BIT 32 @ 12326 <1 @ 12235 18.9 30.6 ROTARY RPM 66 @ 12244 0 @ 12250 33.3 0 PUMP PRESSURE 3231 @ 12268 2054 @ 12241 3005.4 3148 DRILLING MUD REPORT DEPTH: 12295' MW 9.4 VIS 87 PV 21 YP 18 FL 6@300 Gels 10/14/15 CL- 1150 FC SOL 13 SD 17 OIL MBL pH 20 Ca+ ,25 MVVD SUMMARY INTERVAL TO TOOLS REASON PULLED ftJhr amps Klbs RPM psi CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 38 @ 12235 13 @ 12286 25.2 CU'I-I'ING GAS 0 @ 0 @ 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 7277 @ 12235 1977 @ 12286 4112.1 ETHAN E(C-2) 52 @ 12235 11 @ 12327 21.0 PROPANE(C-3) 17 @ 12235 3 @ 12307 7,3 BUTANE(C-4) 7 @ 12258 1 @ 12284 1,6 PENTANE(C-5) 0 @ 12328 0 @ 12328 0,0 HYDROCARBON SHOWS MINOR COAL GAS INTERVAL LITHOLOGY/REMARKS TRIP GAS= 335 WIPER GAS= S U RVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 20 GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONES INTERBEDDED WITH CONGLOMERATES AND THIN COALS PRESENT LITHOLOGY COAL 20% TUFFACEOUS SlLTSTONE 30% TUFFACEOUS CLAYSTONE 30% SAND 20% DALLY ACTIVITY SUMMARY PULL OUT OF HOLE TEST BOP- PUT ON NEW BHA AND NEW BIT-PU 5" DP- REAM 30' TO BO'FTOM-RESUME DRILLING Epoch Personel On Board= 4 Daily Cost $2363 Report by: GEORGE BAKER FOREST OIL DALLY WELLSITE REPORT REDOUBt UNIT #2 REPORT FOR M. MURRAY/D. JONES DATE Mar 30, 2001 DEPTH 12815 TIME 4AM YESTERDAY 12328 24 Hour Footage 487 CASING INFORMATION 9.625" @ 9011' DEPTH SURVEY DATA 12704.55' EPOCH PRESENT OPERATION= CIRC. BTMS UP BEFORE TRIP INCLINATION 38.63 AZIMUTH VERTICAL DEPTH 127.03 10473.51' BIT INFORMATION NO, SIZE 8 8.5" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,3 VIS FC SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I-I'ING GAS TYPE SIN HTC MX-R18DD JS4028 86 PV 11.5 SD METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) 230.2 1035 46 70 3297 INTERVAL JETS IN OUT 3x18 12234' HIGH LOW @ 12513 4.7 @ @ 12543 208 @ @ 12386 6 @ @ 12759 60 @ @ 12404 2141 @ DEPTH: 12800' 18 YP 14 FL OIL 73.5 MBL FOOTAGE HOURS 28.57 CONDITION T/B/C AVERAGE CURRENT AVG 12573 31.5 7.4 12365 643.0 1025.1 12578 33.1 37.4 12671 64 64 12677 3179.3 2874 5@300 Gels 8/12/14 CL- pH Ca+ HIGH LOW AVERAGE 218 @ 12518 8 @ 12711 34.8 o @ o @ o.o CHROMATOGRAPHY(ppm) 37738 @ 12518 1503 @ 12711 5800.5 108 @ 12518 1 @ 12409 19.2 36 @ 12518 1 @ 12411 7.7 168 @ 12518 1 @ 12787 19.5 o @ o @ o.o REASON PULLED ft/hr amps KIbs RPM psi 30000 CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 25 HYDROCARBON SHOWS MINOR COAL GAS SHOWS INTERVAL LITHOLOGY/REMARKS GAS LITHOLOGY TUFFACEOUS CLAYSTONE SECTION WITH THIN COALS PRESENT LITHOLOGY 30% COAL 40% TUFFACEOUS CLAYSTONE 30% TUFFACEOUS SILTSTONE DESCRIPTION DAILY ACTIVITY SUMMARY DRILLING AHEAD TO 12815'- CIRCULATE BO'I-rOMS UP-PREPARE TO TRIP OUT Epoch Personel On Board= 4 Daily Cost $2363 Report by: GEORGE BAKER FOREST OIL REDOUBT'UNIT #2 REPORT FOR M. MURRAY/D. JONES DATE MARCH 31,2001 , TIME 4am CASING INFORMATION 9.625" @ 9011' DAILY WELLSITE REPORT DEPTH 12815 YESTERDAY 12815 24 Hour Footage 0 EPOCH DEPTH INCLINATION SURVEY DATA 12704,55' 38.63 PRESENT OPERATION= WASH AND REAM TO BTM AZIMUTH VERTICAL DEPTH 127.03 10473.51' iii BIT INFORMATION NO. SIZE TYPE 8 8.5" HTC MX-R18DD 9 8,5" STC 25MFDP DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE VVEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 FC MWD SUMMARY INTERVAL TO TOOLS INTERVAL S/N JETS IN OUT JS4028 3x18 12234 12815 LW7171 3x18 12815 HIGH 20.8 @ 12803 7.4 1025 @ 12790 720 45 @ 128O6 23 64 @ 12790 64 3412 @ 12809 2680 VIS PV SOL SD FOOTAGE HOURS 580 28.6 LOW AVERAGE @ 12790 14.2 @ 12794 899.7 @ 12796 41,3 @ 12815 64 @ 12792 3308,6 DEPTH: 12800 YP FL OIL MBL ii i i GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 24 @ 12795 18 @ 12798 22.9 CuI-rlNG GAS 0 @ 0 @ 0,0 CHROMATOGRAPHY(ppm) METHANE(C-I) 4016 @ 12795 3043 @ 12798 3629.6 ETHANE(C-2) 16 @ 12805 11 @ 12790 14.3 PROPANE(C-3) 7 @ 12805 5 @ 12815 5.8 BUTANE(C-4) 0 @ 12815 0 @ 12815 0,0 PENTANE(C-5) 0 @ 12815 0 @ 12815 0,0 HYDROCARBON SHOWS COAL GAS SHOWS INTERVAL LITHOLOGY/REMARKS GAS LITHOLOGY DRILLING A CLAYSTONE SECTION WITH COALS PRESENT LITHOLOGY 70% TUFFACEOUS CLAYSTONE 30% TUFFACEOUS SILTSTONE TRIP OUT FOR NEW BIT AND BHA- TRIP IN W/NB#9- WASH AND REAM TO BOTTOM DAILY ACTIVITY SUMMARY BOTTOM CONDITION REASON T/B/C PULLED CURRENT AVG 13,0 ft/hr 879.0 amps 43,0 Klbs 64 RPM 3410 psi Gels CL- pH Ca+ CCI TRIP GAS= 188 WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BACKGROUND/AVG 25 DESCRIPTION Epoch Personel On Board= 4 Daily Cost $2363 Report by: GEORGE BAKER FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 01, 2001 TIME 03:54:03 DAILY WELLSITE REPORT DEPTH 13143 YESTERDAY 12815 24 Hour Footage 328 EPOCH PRESENT OPERATION= DRILLING AHEAD CASING INFORMATION 9.625"@ 9011' SURVEY DATA DEPTH INCLINATION 12989.56 37.88 AZIMUTH VERTICAL DEPTH 126.58 10696.23 BIT INFORMATION NO. SIZE TYPE 9 8.5 STC 25MFDP DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW VIS FC SOL MVVD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) SIN JETS LW7171 3X18 HIGH 290,9 @ 1093 @ 43 84 @ 3410 @ INTERVAL IN OUT 12815 12827 12907 12815 12907 12815 4.2 79 9 0 1995 LOW PV SD CONDITION FOOTAGE HOURS T/B/C 19.3 AVERAGE CURRENTAVG 12877 25.6 52.0 12985 542.7 910.2 12816 34.5 22.2 12990 39.8 64 12878 2928.2 2852 REASON PULLED fi/hr amps KIbs RPM psi DEPTH: 12815' YP OIL HIGH LOW AVERAGE 110 @ 12830 5 @ 13142 26.1 0 @ 13143 0 @ 13143 0,0 CHROMATOGRAPHY(ppm) 21629 @ 12830 1033 @ 13142 4683.0 71 @ 12830 1 @ 12957 15.6 38 @ 12830 1 @ 12983 6,9 40 @ 12886 I @ 13111 12.0 8 @ 13033 1 @ 13017 0,4 FL Gels CL- MBL pH Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT CURRENT BAOKGROUND/AVG 22 HYDROCARBON SHOWS INTERVAL COAL GAS SHOWS LITHOLOGY/REMARKS LITHOLOGY TUFFACEOUS CLAYSTONE INTERBEDDED WITH THIN COALS AND SANDS PRESENT LITHOLOGY 50% TUFFACEOUS CLAYSTONE 30% TUFFACEOUS SILTSTONE 20% SAND GAS DESCRIPTION DALLY ACTIVITY SUMMARY DRILLING AHEAD- SURVEY EVERY STAND Epoch Personel On Board= 4 Daily Cost 2363 Report by: GEORGE BAKER FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 03, 2001 TIME 04:00 CASING INFORMATION 9.625"@ 9011' SURVEY DATA BIT INFORMATION NO. SIZE 10 8.5 TYPE STC 25MFODPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DAILY WELLSITE REPORT EPOCH DEPTH 13514 YESTERDAY 13255 24 Hour Footage 259 DEPTH 13372.08 SIN JETS LW7172 3X18 HIGH 130.7 @ 13316 1297 @ 13386 54 @ 13344 121 @ 13386 3256 @ 13261 INCLINATION 38,05 INTERVAL IN OUT 13255 LOW 7.2 @ 249 @ 2 @ 12 @ 2324 @ PRESENT OPERATION= DRILLING FORMATION AZIMUTH VERTICAL DEPTH 129.03 11001.50 CONDITION FOOTAGE HOURS T/B/C 16,5 AVERAGE CURRENT AVG 13464 24.1 24.3 13484 603.2 516,9 13381 33,3 40,5 13484 50.9 40 13336 3061.8 3105 REASON PULLED ft/hr amps Klbs RPM psi DRILLING MUD REPORT MW 9.5 VIS FC /2 SOL PV SD DEPTH: 13480' 17 YP OIL 15 76% FL MBL Gels pH 10/13/15 CL- 25500 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUT]'ING GAS HIGH 132 @ o @ 22720 @ 13318 324 @ 13387 113 @ 13387 0 @ o 0 @ 0 AVERAGE 33.5 0.0 5410,1 25.3 8,3 o 0.0 TRIP GAS= 209/13255 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND~VG 30 LOW 13385 11 @ 13256 o o @ o CHROMATOGRAPHY(ppm) METHANE(C-I) 1357 @ 13256 ETHANE(C-2) 8 @ 13378 PROPANE(C-3) 1 @ 13281 BUTANE(C-4) 0 @ 0 PENTANE(C-5) 0 @ 0 HYDROCARBON SHOWS NO OIL SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 60% CLAY, 20% SAND, 10% SILT, 10% COAL PRESENT LITHOLOGY 13490' = COAL 30% CLAY 60% SILT/ASH 10% DAILY ACTIVITY SUMMARY FINISH TRIPPING IN HOLE, DRILL AHEAD FROM 13255'. Epoch Personel On Board= 4 Daily Cost $2363 Report by: LEES F, BROWNE JR. FOREST OIL REDOUBT UNIT #2 REPORT FOR DON JONES DATE Apr 05, 2001 TIME 04:00 DALLY WELLSITE REPORT EPOCH DEPTH 13831 YESTERDAY 13822 24 Hour Footage 9 PRESENT OPERATION= DRILLING FORMATION CASING INFORMATION 9.625" @ 9011' SURVEY DATA DEPTH 13658.78' INCLINATION AZIMUTH VERTICAL DEPTH 37.71 129.97 11227.30' BIT INFORMATION NO. SIZE 10 8.5 11 8.5 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT TYPE STC 25MFODPS STC MF25TODPS MW 9.5 VIS 75 PV FC /2 SOL 11.21 SD TO MWD SUMMARY INTERVAL TOOLS GAS SUMMARY(units) HIGH DITCH GAS 98 @ CUTTING GAS 0 @ METHANE(C-I) 17538 ETHANE(C-2) 55 PROPANE(C-3) 18 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED LW7172 3X18 13255 13823 568 30.03 2/3-E-I HRS LK3931 3X18 13823 1.5 HIGH LOW AVERAGE CURRENT AVG 65.5 @ 13825 9.9 @ 13827 25.7 14.8 fi/hr 847 @ 13828 166 @ 13831 604.7 166.1 amps 39 @ 13822 10 @ 13823 25.5 15.6 Klbs 68 @ 13822 8 @ 13831 42.8 8 RPM 3302 @ 13826 2176 @ 13824 2887.4 2582 psi DEPTH: 13823' 17 YP 13 FL Gels 8/13/14 CL- 25000 OIL 75.5 MBL pH Ca+ CCI LOW AVERAGE 13826 30 @ 13822 75.3 TRIP GAS= 437/13823 0 0 @ 0 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 13826 4861 @ 13822 12496,1 CONNECTION GAS HIGH= 0 13824 19 @ 13831 40.2 AVG= 0 13824 7 @ 13830 13,4 CURRENT 0 0 0 @ 0 0.0 CURRENT BACKGROUND/AVG 40 0 0 @ 0 0.0 NO OIL SHOWS LITHOLOGY/REMARKS GAS DESCRIPTION LiTHOLOGY SILTSTONE WITH VARIOUS COAL BEDS PRESENT LITHOLOGY 13830'= SILT 60%, SAND 20%, ASH 10%, CONGLOMERATE 10% DAILY ACTIVITY SUMMARY FINISH TRIPPING OUT OF THE HOLE, LAY DOWN AND PICK UP NEW JARS, CHANGE OUT MWD PULSATOR AND FLOAT, PULL WEAR BUSHING, PICK UP TEST PLUG, TEST BOPE, CHOKE MANIFOLD, TEST FLOW, TRIP TANK, PVT AND ACCUMULATOR ALARMS, PULL TEST PLUG, SET W.R., LAY DOWN CROSS OVER'S, RUN IN HOLE WITH BHA, TEST MWD, RUN IN HOLE, SLICK AT 12100', WASH TO BOTTOM FROM 13700'. Epoch Personel On Board= 4 Daily Cost $2363 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE Apr 06, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 14255 YESTERDAY 13831 24 Hour Footage 424 PRESENT OPERATION= DRILLING FORMATION CASING INFORMATION 9.625" @ 9011' SURVEY DATA DEPTH INCLINATION 14042.63 37.79 AZIMUTH VERTICAL DEPTH 129.91 11527,75 BIT INFORMATION NO. SIZE TYPE 11 8.5 STC MF25TODPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE INTERVAL SIN JETS IN OUT LK3931 3X18 13823 HIGH LOW 193,2 @ 13928 8.4 @ 1088 @ 14201 SLIDE 85 @ 14165 9 88 @ 13870 SLIDE 3418 @ 14207 1629 CONDITION FOOTAGE HOURS T/B/C 21.24 AVERAGE CURRENT AVG 14053 29.6 23.1 14022 529.2 824.1 14196 40.1 40.9 14091 39.4 65 14196 3218.9 3261 REASON PULLED ftJhr amps Klbs RPM psi DRILLING MUD REPORT MW 9.5 VIS 71 FC /2 SOL 12 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH 218 @ o @ METHANE(C-I) 38089 ETHANE(C-2) 114 PROPANE(C-3) 23 BUTANE(C-4) 0 PENTANE(C-5) 0 DEPTH: 14214 PV 18 YP 14 FL SD OIL 76% MBL LOW AVERAGE 14002 13 @ 14186 42,0 o o @ o o.o CHROMATOGRAPHY(ppm) 14001 2096 @ 14186 6676.5 14001 5 @ 14186 20.3 14003 1 @ 14159 6.7 o o @ o o.o o o @ o o.o Gels 12/16/18 CL- pH Ca+ 24000 CCI TRIP GAS= 0 WIPER GAS= 57/14196 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 39 HYDROCARBON SHOWS NO OIL SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY SAND 20%, ASH 20%, CLAY 10%, SILT 50% PRESENT LITHOLOGY 14250-14255'= 50% COAL, 20% CARB SHALE, 20% SILT, 10% CLAY GAS DESCRIPTION , ,, DALLY ACTIVITY DRILL AHEAD FROM 13823', DRILL AHEAD TO 14196', PICK UP 3 JOINTS OF DRILL PIPE, 57 UNITS WIPER GAS, DRILL SUMMARY AHEAD. Epoch Personel On Board: 4 Daily Cost $2363 Report by: LEES F, BROWNE JR, FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE Apr 07, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14320 YESTERDAY 14255 24. Hour Footage 65 CASING INFORMATION 9.625" @ 9011' SURVEY DATA EPOCH BIT INFORMATION NO. SIZE TYPE 11 8.5 STC MF25TODPS PRESENT OPERATION= ON BOTTOM AFTER WIPER TRIP DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 14320 38.91 130.61 11745 S/N LK3931 JETS 3X18 INTERVAL IN 13823 OUT 14320 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 497 23.12 NA TD DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE 145.0 1071 42 84 3396 HIGH 14301 14294 14292 14294 14317 LOW AVERAGE CURRENTAVG 8.6 @ 14256 25.7 17.6 Whr 415 @ 14320 895.1 415.7 amps 26 @ 14300 38,0 39.5 Klbs 26 @ 14320 70.8 26 RPM 2633 @ 14293 3310.5 3386 psi DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'Iq'ING GAS VIS SOL HIGH 48 @ o @ METHANE(C-I) 8148 ETHANE(C.2) 32 PROPANE(C-3) 11 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL PV DEPTH: YP FL Gels CL- OIL MBL pH Ca+ LOW AVERAGE 14273 22 @ 14298 35.8 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) 14273 5032 @ 14298 5883.2 14273 8 @ 14306 16.6 14260 1 @ 14308 6.3 0 0 @ o o.o o o @ o o.o NO OIL SHOWS LITHOLOGY/REMARKS CCI TRIP GAS= 0 WIPER GAS= 227/14320 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 70 GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONES GRADING TO VERY ARGILLACEOUS SANDSTONES PRESENT LITHOLOGY 14320' = 60% SILT, 10% ASH, 20% SANDSTONE, 10% SAND DALLY ACTIVITY SUMMARY DRILL FORMATION TO 14320', CIRCULATE HI VIS SWEEP, PUMP 12 STANDS OUT OF THE HOLE, RUN BACK IN THE HOLE AND WASH DOWN FROM 14120', CIRCULATE OUT 227 UNITS OF WIPER GAS, PUMP SWEEP AND PULL PIPE UP INTO THE SHOE, MONITOR WELL, CUTAND SLIP DRILL LINE, RUN BACK IN THE HOLE, TIGHTAT 14265', WASH DOWN TO 14305', TIGHT HOLE, WASH TO BOTTOM, CIRCULATE BOTTOMS UP. Epoch Personel On Board= 1 Daily Cost $2108 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 10, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 14320 YESTERDAY 14320 PRESENT OPERATION= TRIP IN AFTER LOGS/WIPER 24 Hour Footage 0 CASING INFORMATION 9.625" @ 9011' DEPTH SURVEY DATA INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE rtl 1 8.5 STC MF25TODPS LK3931 3X18 14320 DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 0 @ 0 0 @ 0 0 SURFACE TORQUE 0 @ 0 0 @ 0 0 WEIGHT ON BIT 0 @ 0 0 @ 0 0 ROTARYRPM 0 @ 0 0 @ 0 0 PUMP PRESSURE 0 @ 0 0 @ 0 0 DRILLING MUD REPORT DEPTH: MW VIS PV YP FC SOL SD OIL HOURS CONDITION REASON 'F/B/C PULLED CURRENT AVG 0 ftJ'hr 0 amps 0 Klbs 0 RPM 0 psi FL Gels CL- MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0 CUTTING GAS 0 @ 0 0 @ 0 0 CHROMATOGRAPHY(ppm) METHANE(C-I) 0 @ 0 0 @ 0 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY 14320' = 20% SAND, 10% SANDSTONE, 10% ASH, 60% SILT DAILY ACTIVITY SUMMARY TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION MAKE UP WIRE LINE TOOLS, RUN IN HOLE WITH VARIOUS TOOLS, LOG, FINISH LOGGING. RUN IN THE HOLE WITH BHA AND HWDP (RRBIT #11), RUN IN HOLE FOR WIPER RUN. Epoch Personel On Board= 1 Daily Cost $2108 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 11, 2001 TIME 04:00 CASING INFORMATION 9.625" @ 9011' SURVEY DATA DALLY WELLSITE REPORT EPOCH DEPTH 14320 YESTERDAY 14320 24 Hour Footage 0 PRESENT OPERATION= PREP TO RUN CASING DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 11rr 8.5 STC MF25TODPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.7 VIS 8O FC ~2 SOL 11.7 INTERVAL SIN JETS IN LK3931 3X18 14320 OUT 14320 HIGH LOW o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o CONDITION REASON FOOTAGE HOURS T/B/C PULLED 0 0 3/4-E-I CSG DEPTH: 14320' PV 19 YP 12 SD OIL 76.5% AVERAGE CURRENT AVG 0 0 fi/hr 0 0 amps 0 0 Klbs 0 0 RPM 0 0 psi FL Gels 10/15/19 CL- MBL pH Ca+ 21000 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 458 @ 14320 20 @ 14320 75 CUTTING GAS 0 @ 0 0 @ 0 0 CHROMATOGRAPHY(ppm) METHANE(C-I) 0 @ 0 0 @ 0 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY 14320' = SAND 20%, SANDSTONE 10%, ASH 10%, SILT 60% DALLY ACTIVITY SUMMARY TRIP GAS= 458 WIPER GAS= 128/75/30 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION RUN IN HOLE WITH BIT #1 lrr FOR WIPER TRIP, RUN IN THE HOLE TO 8972', CIRCULATE MUD, CUT AND SLIP DRILL LINE, RUN IN THE HOLE TO BOTTOM, TIGHT AT 11230, 13200 AND HAD TO WASH AND REAM FROM 13990 TO 14320', CIRCULATE BOTTOMS UP = 458 UNITS TRIP GAS, MAKE A SEVEN STAND SHORT TRIP, TIGHT AT 13850-13900, WASH THE LAST 90' TO BOTTOM, CIRCULATE OUT 128 UNITS OF WIPER GAS, PULL OUT TO 13175, HOLE TIGHT AT 14290, RUN IN THE HOLE TO 14290, TOOK 40K GOING DOWN TO REAM THROUGH, CIRCULATE AND SWEEP HOLE, WIPER GAS = 75 UNITS, PULL OUT OF THE HOLE TO 13700, TIGHT AT 14290', RUN INTO THE HOLE TIGHT AND NO FILL, CIRCULATE AND PUMP HI VIS SWEEP, WIPER GAS = 30 UNITS, PULL OUT OF THE HOLE, TIGHT AT 14290', AND PREP FOR RUNNING CASGING. Epoch Personel On Board= 1 Daily Cost $2108 Report by: LEES F, BROWNE JR. FOREST OIL CORP. REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 12, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14320 YESTERDAY 14320 24 Hour Footage 0 CASING INFORMATION 9.625" @ 9011' 7.625" @ DEPTH SURVEY DATA INCLINATION EPOCH PRESENT OPERATION= TRIP IN WITH CSG AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE SIN INTERVAL JETS IN OUT F O OTAG E CONDITION REASON HOU RS T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE HIGH LOW o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o AVERAGE CURRENT AVG 0 0 ft/hr 0 0 amps 0 0 Klbs 0 0 RPM 0 0 psi DRILLING MUD REPORT MW VIS PV FC SOL SD DEPTH: YP FL Gels CL- OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 113 @ 14320 15 @ 14320 50 CUTTING GAS 0 @ 0 0 @ 0 0 CHROMATOGRAPHY(ppm) METHANE(C-I) 0 @ 0 0 @ 0 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 PENTANE(C-5) 0 @ o 0 @ 0 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS TRIP GAS= 0 WIPER GAS= 113/5533' SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 14320' = 20% SAND, 10% SANDSTONE, 10% ASH, 60% SILT DALLY ACTIVITY SUMMARY CHANGE BOTTOM RAMS, TEST DOORS-SEALS, INSTALL WITH BUSHING AND LAY TEST JOINTS, RIG UP AND RUN 7 5/8" CASING, RUN 135 JOINTS, PICK UP AND MAKE UP HANGER AND RUN IN HOLE ONE STAND 5" HANGER IN 9 5/8", SHOE AT 5629', CIRCULATE LINER VOL. +40 SPM/3.4 BBL/MIN, 800 PSI, 113 UNITS BOTTOMS UP GAS, CONTINUE TO RUN TO BOTTOM. Epoch Personel On Board= 1 Dally Cost $2108 Report by: LEES F, BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 13, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14320 YESTERDAY 14320 24 Hour Footage 0 EPOCH CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' DEPTH SURVEY DATA PRESENT OPERATION= PULLING DRILL PIPE INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 ft/hr SURFACE TORQUE 0 @ 0 0 @ 0 0 0 amps WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 Klbs ROTARY RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 psi DRILLING MUD REPORT DEPTH: MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI HYDROCARBON SHOWS INTERVAL GAS DESCRIPTION MWD SUMMARY INTERVAL TO TOOLS , , GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0323 @ 14320 55 @ 14320 176 TRIP GAS= 323/14320 CU'ITING GAS 0 @ 0 0 @ 0 0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-I) 21784 @ 14320 0 @ 0 0 CONNECTION GAS HIGH= 0 ETHANE(C-2) 46 @ 14320 0 @ 0 0 AVG= 0 PROPANE(C-3) 11 @ 14320 0 @ 0 0 CURRENT 0 BUTANE(C-4) 0 @ 14320 0 @ 0 0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 14320 0 @ 0 0 NO SHOWS LITHOLOGY/REMARKs LITHOLOGY PRESENT LITHOLOGY 14320' = 20% SAND, 10% SANDSTONE, 10% ASH, 60% SILT DAILY ACTIVITY RUN LINER TO BOTTOM, CIRCULATE BACK 323 UNITS OF TRIP GAS, CONTINUE TO CIRCULATE, PUMP CEMENT, CIRCULATE SUMMARY OUT 100 UNITS OF GAS, BEGIN TO PULL DRILL PIPE OUT OF THE HOLE. Epoch Personel On Board= 1 Daily Cost $2108 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 14, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14320 YESTERDAY 14320 24 Hour Footage 0 CASINGINFORMATION 9.625"@ 9011'7.625"@ 14320' DEPTH SURVEY DATA EPOCH PRESENT OPERATION= CLEAN RIG AFTER BOP TEST INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS CONDITION REASON T/B/C PULLED DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 0 @ 0 0 @ 0 SURFACE TORQUE 0 @ 0 0 @ 0 WEIGHT ON BIT 0 @ 0 0 @ 0 ROTARY RPM 0 @ 0 0 @ 0 PUMP PRESSURE 0 @ 0 0 @ 0 AVERAGE CURRENT AVG 0 0 fi/hr 0 0 amps 0 0 Klbs 0 0 RPM 0 0 psi DRILLING MUD REPORT MW 9.7 VIS FC ~ SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY DEPTH: 14320' 84 PV 20 YP 11 11.69 SD OIL 76.5% HIGH LOW AVERAGE o @ o o @ o o o @ o o @ o o CHROMATOGRAPHY(ppm) 0 o 0 0 0 FL Gels 10/15/20 CL- MBL pH Ca+ 21000 CCI @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ 0 o NO SHOWS TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 LITHOLOGY/REMARKS GAS DESCRIPTION DALLY ACTIVITY SUMMARY CONTINUE TO PULL AND LAY DOWN DRILL PIPE AFTER CEMENT HAS BEEN PUMPED, PJSM RUN IN THE HOLE WiTH BHA, PULL OUT OF THE HOLE AND LAY DOWN BHA, RUN IN THE HOLE WITH 5" DRILL PIPE, OUT OF DRK 45 STANDS, LAY DOWN, UNLOAD BOAT, TEST CHOKE MANIFOLD, FLOOR VALVES AND UPPER KELLYCOCK VALVES, RUN IN THE HOLE WITH 5" DRILL PIPE, CHANGE OUT BOTTOM RAMS TO 3.5", PULL WEAR BUSHING, SET TEST PLUG, TEST 5" RAMS - KILL LINES AND CHOKE VALVES, PICK UP 3.5" DRILL PIPE, TEST JT AND TEST 3.5" PIPE, TEST ANNULAR, PULL TEST PLUG, SET WEAR RING. Epoch Personel On Board= 2 Daily Cost $1773 w/o SAMPLE CATCHERS Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 15, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14320 YESTERDAY 14320 24 Hour Footage 0 CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' EPOCH PRESENT OPERATION= DRILL OUT LANDING COLLAR SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE 12rr3 6.75 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS TYPE STC XR32TDGPS VIS SOL 116 0 METHANE(C-I) 17043 ETHANE(C-2) 42 PROPANE(C-3) 1 BUTANE(C.4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY 100% CEMENT DAILY ACTIVITY SUMMARY SIN MG1206 INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2X18, 1X20 14320 HIGH LOW AVERAGE CURRENT AVG 0 @ 0 0 @ 0 0 0 fi/hr 0 @ 0 0 @ 0 0 0 amps 0 @ 0 0 @ 0 0 0 Klbs 0 @ 0 0 @ 0 0 0 RPM 0 @ 0 0 @ 0 0 0 psi DEPTH: PV YP FL Gels CL- SD OIL MBL pH Ca+ CCI HIGH LOW AVERAGE @ 14320 8 @ 14320 40 TRIP GAS= 116/14320' @ 0 0 @ 0 0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 @ 14320 0 @ 0 0 CONNECTION GAS HIGH= 0 @ 14320 0 @ 0 0 AVG= 0 @ 14320 0 @ 0 0 CURRENT 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 19 @ o o @ o o NO SHOWS LITHOLOGY/REMARKS GAS DESCRIPTION FINISH TESTING BOPE, LAY DOWTOOLS, PICK UP BHA, STRAP AND PICK UP 3.5" HWDP AND 3.5" DRILL PIPE, SERVICE RIG, CIRCULATE MUD, RUN IN THE HOLE WITH 5" DRILL PIPE, TAG CEMENT AT 14175', DRILL CEMENT TO 14234', CIRCULATE BOTTOMS UP (116 UNITS TRIP GAS), PRESSURE TEST CASGING, DRILL LANDING COLLAR. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 16, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 1442O YESTERDAY 14321 24 Hour Footage 99 PRESENT OPERATION= TRIP OUT FOR CORE #1 CASING INFORMATION 9.625" @ 9011' 7.625"@ 14320' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 12rr3 6.75" STC XR32TDGPS MG1206 2X18, 1X20 14320 14420 100 14.8 NA CP DRILLING PARAMETERS HIGH RATE OF PENETRATION 27.7 @ 14341 SURFACE TORQUE 5269 @ 14395 WEIGHT ON BIT 22 @ 14371 ROTARY RPM 54 @ 14351 PUMP PRESSURE 2882 @ 14331 DRILLING MUD REPORT DEPTH: 14340' MW 9.6 VIS 77 PV 19 YP FC ~ SOL 11.19 SD OIL LOW AVERAGE CURRENT AVG 3.2 @ 14335 10.6 13.1 fi/hr 345 @ 14346 4888.9 5102.9 amps 4 @ 14401 19.9 20.8 Klbs 2 @ 14346 47.6 46 RPM 570 @ 14346 2750.7 2769 psi 12 FL Gels 10/14/19 CL- 77% MBL pH Ca+ 21000 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS C U'I-I'ING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C.4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 14395' TO 14420' 15 0 2541 60 49 36 11 C-4 FIRST NOTED AT 1 HIGH LOW AVERAGE @ 14340 3 @ 14337 6.8 TRIP GAS= 0 @ 0 0 @ 0 0.0 WIPER GAS= 0 CHEOMATOGRAPHY(ppm) SURVEY= 0 @ 14340 127 @ 14370 639.6 CONNECTION GAS.HIGH= 0 @ 14416 1 @ 14390 9.3 AVG= 0 @ 14416 1 @ 14390 7.6 CURRENT 0 @ 14406 4 @ 14396 4.9 CURRENT BACKGROUND/AVG 0 @ 14414 1 @ 14401 1,0 4395' AND >10PPM AT 14400' TO CORE POINT AT 14420' LITHOLOGY/REMARKS 70% SAND, 30% SILT 10% CEMENT CAVINGS GAS DESCRIPTION BEFORE 3 DURING 13 SAND = P[NISH GRAY TO VERY PALE ORANGE, CGR TO MED GR DECR AFTER 13 CORE TO MED TO FINE GR AT 14420', GRAIN AND MATRIX SUPPORT, FAIR POINT OCC GOOD PORO/FAIR PERM. LITHOLOGY PRESENT LITHOLOGY MINOR COAL STRINGERS AT 14340-70', BCMG SANDY COARSE TO MED GR DECR TO MEDIUM TO FINE GRAIN. MODERATE SILT/ASH MATRIX. 14420' = 70% SAND, 30% SILT DAILY ACTIVITY SUMMARY DRILL OUT LANDING COLLAR, FLOAT AND SHOE, DRILL FORMATION FROM 14320' TO 14345', LEAK OFF TEST TO 10.5 MWE, DRILL FORMATION FROM 14345' TO 14400', CIRCULATE BOTTOMS UP, DRILL FORMATION FROM 14400 TO 14420', CIRCULATE UP BOTTOMS UP, BEGIN TO PULL OUT OF THE HOLE FOR CORE #1 Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE Apr 17, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14440 YESTERDAY 14420 24 Hour Footage 20 CASING INFORMATION 9.625"@ 9011' 7.625" @ 14320' DEPTH SURVEY DATA INCLINATION EPOCH PRESENT OPERATION= TRIP OUT w/CORE #1 AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE SIN 12rr3 6.75" STC XR32TDGPS MG 1206 13 6.75" DPI CMM35F 1963827 INTERVAL JETS IN OUT 2X18, 1X20 14320 14420 2X18, 1X20 14420 14440 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 100 14.8 2/2-E-I CP 20 4.1 PR DRILLING PARAMETERS RATE OF PENETRATION 13.1 SURFACE TORQUE 6009 WEIGHT ON BIT 20 ROTARY RPM 51 PUMP PRESSURE 2769 HIGH LOW @ 14420 1,5 @ 14440 @ 14438 5102 @ 14420 @ 14420 4 @ 14421 @ 14435 36 @ 14422 @ 14420 2335 @ 14435 AVERAGE CURRENT AVG 7.8 1.5 ftJhr 5967.1 5532.5 amps 7.5 8.7 Klbs 49.8 5O RPM 2509.2 2365 psi DRILLING MUD REPORT MW 9.5 VIS 79 PV FC /2 SOL 9.99 SD DEPTH: 14420' 21 YP 10 FL OIL 78% MBL Gels 8/15/17 CL- 21000 pH Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH o METHANE(C-I) 1210 @ ETHANE(C-2) 31 @ PROPANE(C-3) 22 @ BUTANE(C-4) 16 @ PENTANE(C-5) 3 @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS 14420' TO 14440' SAND = 60-80% SILT = 40- BEFORE 8 2O% DURING 5 ENDING 4 LITHOLOGY SAND 70%, SILT 30% PRESENT LITHOLOGY 14435' = SAND 80%, SILT 20% LOW AVERAGE 14421 4 @ 14429 4.7 0 0 @ 0 0,0 CHROMATOGRAPHY(ppm) 14421 193 @ 14435 481.1 14424 9 @ 14435 15.1 14424 3 @ 14435 8.3 14424 1 @ 14427 4.2 14420 3 @ 14420 0,1 DECR C-4'S THROUGH OUT CORE 14420 - 14440' CCI TRIP GAS= 10/14420' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 DESCRIPTION SAND = VERY LIGHT GRAY, CLAST SIZE FROM MED LOWER TO FINE LOWER, PRED GRAIN SUPPORT w/SEC SILT MATRIX SUPPORT, FAIR INCR TO GOOD PORO & PERM, FINISH PULLING OUT OF THE HOLE WITH BIT #12rr3, LAY DOWN BHA AND REMOVE FROM THE RIG FLOOR, PICK UP CORE DAILY ACTIVITY BARREL, SPACE OUT INNER CORE BARREL, TEST SURVEY TOOL, RUN IN THE HOLE WITH BHA, PICK UP 9 JOINTS OF 4 3/4" SUMMARY DC'S, CUT AND SLIP DRILL LINE, SERVICE RIG, RUN IN THE HOLE AND WASH TO BOTTOM, CORE FROM 14420'. Epoch Personel On Board= 2 Daily Cost $2123 w/CATCHERS ON STANDBY Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE Apr 18, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 14475 YESTERDAY 14440 24 Hour Footage 35 PRESENT OPERATION= TRIP OUT W/CORE #2 CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 13 6.75 DPI CMM35F 13rr2 6.75 DPI CMM35F DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE SIN 1963827 963827 19.5 6323 10 5O 2428 INTERVAL JETS IN OUT 2X18,1X20 14420 14440 2X18,1X20 14440 14475 HIGH LOW @ 14469 1.5 @ @ 14470 4671 @ @ 14464 2 @ 14440 33 @ @ 14443 2080 @ CONDITION REASON FOOTAGE HOURS T/B/C PULLED 20 4.1 0/0-X-I PR 35 5.6 NA NA AVERAGE CURRENT AVG 14440 9.7 5.0 fi/hr 14441 5989.7 5807.6 amps 14441 7.9 8.6 Klbs 14441 46.7 45 RPM 14441 2444.2 2331 psi DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU']-FING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) DEPTH: VIS PV YP SOL SD OIL HIGH LOW 9 14459 2 @ 14454 2.6 0 14475 0 @ 14475 0.0 CHROMATOGRAPHY(ppm) 1195 @ 14459 224 @ 14454 239.9 38 @ 14459 6 @ 14454 7.2 31 @ 14459 3 ~ 14440 6.9 24 @ 14459 2 @ 14445 4,7 16 @ 14459 5 @ 14458 0,6 AVERAGE FL Gels CL- MBL pH Ca+ , CCI TRIP GAS= 7/14440' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 HYDROCARBON SHOWS INTERVAL 14457' TO 14458' BEGIN READING >10 PPM C-4 & C-5 AT 14457', 14459' to 14475' NOT CIRCULATED OUT, LITHOLOGY/REMARKS GAS DESCRIPTION SAND 100% FROM SHAKERS BEFORE 4 DURING 9 C-4 & C-5 GREATER THAN 10 PPM STARTING AT 14457 TO 144458'. INCREASE IN ROP END(TRIP) 9 UNITS 14459 TO 14475 NOT CIRCULATED UP AND LOGGED AFTER THE TRIP. LITHOLOGY 14422' TO 14435' = CONGLOMERATE SAND 20%, CONGLOMERATE 20%, SANDSTONE 50%, SAND 10% PRESENT LITHOLOGy 14455'= 80% SAND, 20% CONGLOMERATE FROM SHAKER SCREENS. 14459' - 14475' NOT CIRC OUT CORE FROM 14420 TO 14440', CORE JAM, PULL UP TO 14310', DROP DART AND PUMP DRY JOB, PULL OUT OF THE HOLE, PJSM DAILY STAND BACK DRILL COLLARS AND LAY DOWN INNER CORE BARREL, RECOVERED 14' OF CORE, PICK UP NEW INNER CORE ACTIVITY SUMMARY BARREL, MAKE UP INNER CORE BARREL, INSTALL ESS SURVEY, RUN IN THE HOLE WITH BHA AND 3.5" DRILL PIPE, SERVICE RIG, RUN IN THE HOLE AND WASH 30' TO BOTTOM, CORE FROM 14440 TO 14475', BEGIN TO PULL OUT OF THE HOLE WITH CORE #2. Epoch Personel On Board: 2 Daily Cost $2123 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE Apr 21, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14567 YESTERDAY 14558 24 Hour Footage 9 INCLINATION 35.25 CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14438.24 [:::1 EPOCH PRESENT OPERATION= TRIP OUT W/CORE # 5 AZIMUTH VERTICAL DEPTH 129.93 11841.0 BIT INFORMATION NO. SIZE TYPE SIN 14rrl 6.75 DPI CMM35F 1963828 14rr2 6.75 DPI CMM35F 1963828 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.5 VIS FC /1 SOL 74 10.24 MWD SUMMARY INTERVAL TO TOOLS JETS 2X18,1X20 2X18,1X20 INTERVAL IN 14537 14558 HIGH 4.6 @ 14566 0.8 5885 @ 14566 3372 8 @ 14558 4 47 @ 14562 24 2475 @ 14560 1758 DEPTH: 14558' PV 20 YP 11 SD OIL 77% CONDITION REASON OUT FOOTAGE HOURS T/B/C PULLED 14558 21 4.2 NA PR 14567 9 4.2 NA PR LOW AVERAGE CURRENT AVG @ 14567 3.0 0.8 ft/hr @ 14559 6055.5 5586.9 amps @ 14562 7.1 7.2 Klbs @ 14559 48.7 47 RPM @ 14559 2582.9 2306 psi FL Gels 7/11/14 CL- MBL pH Ca+ 20000 CCI GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH LOW AVERAGE 4 @ 14558 2 @ 14561 2.7 o @ o o @ o o CHROMATOGRAPHY(ppm) 401 @ 14558 136 @ 14561 166.1 37 @ 14558 14 @ 14561 16.8 24 @ 14558 9 @ 14561 11.1 1 @ 14558 1 @ 14558 0.1 o @ o o @ o o TRIP GAS= 5 / 14558 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 HYDROCARBON SHOWS INTERVAL NO SHOWS OF C-4 OR C-4 DURING CORE # 5 LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATE SAND AND CONGLOMERATE (LOOSE PACKING/SOFT SEDIMENT) PRESENT LITHOLOGY 14558' = 50% CONGLOMERATE SAND 50% CONGLOMERATE DAILY ACTIVITY SUMMARY PULL OUT OF THE HOLE WITH CORE #4 AND STAND BACK BHA, HOLD PRE JOB SAFTEY MEETING, LAY DOWN CORE ¢4, RUN IN THE HOLE WITH 3.5" DRILL PIPE, SERVICE RIG, REAM 25' TO THE Bo'FrOM OF THE HOLE, CORE FROM 14558' TO 14567', PULL UP AND DROP DART, BEGIN TO PULL OUT WITH CORE #5. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 24, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14610 YESTERDAY 14594 24 Hour Footage 16 CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14620' INCLINATION BIT INFORMATION NO. SIZE TYPE 12rr2 6.75" STC XR32TDGPS 15 6.75" DPI GDBC DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,5 VIS 82 FC /1 SOL 10.74 MWD SUMMARY INTERVAL TO TOOLS S/N MG12O6 96003 5.3 6336 25 64 3112 PV SD JETS 2X18,1X20 INTERVAL IN OUT 14567 14594 14594 HIGH @ 14594 2.0 @ 14598 3786 @ 14594 4 @ 14597 29 @ 14594 1824 LOW 12 77% DEPTH: 14607' 19 YP OIL 14603 14595 14595 14595 14604 FL MBL AZIMUTH EPOCH PRESENT OPERATION= CORE # 6 FOOTAGE HOURS 27' 6.3 9.8 AVERAGE 2.9 6265.2 11.4 63.9 2098.1 VERTICAL DEPTH 11980' CONDITION REASON T/B/C PULLED 3/6-E-I CP CURRENT AVG 2.9 ff./hr 6135.7 amps 11.5 Klbs 62 RPM 1898 psi Gels 7/14/19 CL- 20000 pH Ca+ CCI GAS SUMMARY(units) HIGH DITCH GAS 6 @ cu%rING GAS 0 METHANE(C-I) 601 @ ETHANE(C-2) 23 PROPANE(C-3) 13 @ BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL AVERAGE 4.3 0,0 LITHOLoGY SAMPLES SHOW 99% G-SEAL (GRAPHITE) MUD PRODUCT PRESENT LITHOLOGY 99% GRAPHITE MUD PRODUCT, 1% SAND LOW 14594 3 @ 14597 o o @ o CHROMATOGRAPHY(ppm) 14594 137 @ 14602 207.1 14594 8 @ 14596 14,6 14594 5 (~ 14610 7.4 o o @ o o.o 0 o @ 0 0.0 NO SHOW OF C-4 (14594' TO 14610') LITHOLOGY/REMARKS DALLY ACTIVITY SUMMARY TRIP GAS= 5/14594' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 4 GAS DESCRIPTION PULL OUT OF THE HOLE WITH 3.5" DRILL PIPE, LAY DOWN BY PASS SUB AND REMOVE DART, PULL OUT OF THE HOLE WITH BHA, HOLD PRE JOB SAFETY MEETING, RETRIEVE MULTI SHOT SURVEY, LAY DOWN DRILLING BHA, CLEAN RIG FLOOR, HOLD PRE JOB SAFETY MEETING, MAKE UP CORE BHA AND RUN IN THE HOLE WITH 3.5" DRILL PIPE, CHANGE OUT 3,5" HANDLING TOOLS TO 5", TRIP IN THE HOLE WITH 5" DRILL PIPE, WASH AND REAM TO BOTTOM, BIT PLUGGED, STAND BACK 3 STANDS AND CIRCULATE SLOWLY AT THE SHOE, CLEAN OUT PLUGGED STRING, WASH FROM 14320' TO 14563', REAM FROM 14563' TO 14594', BEGIN CORING. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 25, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 14636 YESTERDAY 14610 24 Hour Footage 26 PRESENT OPERATION= CORE #7 FROM 14622' CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14661' INCLINATION AZIMUTH VERTICAL DEPTH 12012' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 15 6.75" DPI GDBC 96003 14594 14621 27 10.7 6/4-1 PR 14rr3 6.75" DPI CMM35F 1963828 2X18, 1X20 14621 5.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 25.2 @ 14627 1.0 @ 14622 9.1 18.8 ftJhr SURFACE TORQUE 7080 @ 14627 4919 @ 14622 6631.9 6882.5 amps WEIGHT ON BIT 11 @ 14621 4 @ 14622 10.9 9.9 Klbs ROTARY RPM 63 @ 14621 33 @ 14622 54.7 46 RPM PUMP PRESSURE 2398 @ 14625 1819 @ 14621 2202.7 2367 psi DRILLING MUD REPORT DEPTH: 14607' MW 9.5 VIS 82 PV 19 YP 12 FL Gels 7/14/19 CL- 20000 FC \1 SOL 10.74 SD OIL 77% MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 4 @ 14612 3 @ 14622 4.,5 TRIP GAS= 5 / 14621' CUTTING GAS 0 @ 0 0 @ 0 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-I) 474 @ 14619 169 @ 14621 289.4 CONNECTION GAS HIGH= 0 ETHANE(C-2) 23 @ 14636 8 @ 14620 15.1 AVG= 0 PROPANE(C-3) 7 @ 14622 3 @ 14634 4.7 CURRENT 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 4 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS NO SHOWS OF C-4 OR C-5 LAST 24 HRS (SLIGHT DEAD OIL TAR @14594 - 14597' AND @ 14600-14603') INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 14597' TO 14618'= 90% SANDSTONE (DENSE IN PARTS), 10% SILTSTONE PRESENT LITHOLOGY SAMPLES OVER SHAKER = 100% GRAPHITE MUD PRODUCT CORE #6 TO 14621' PULL OUT, TIGHT AT 14595', PUMP BYPASS DART DOWN AND PUMP DRY JOB, TRIP OUT WITH 5" DRILL PIPE DAILY ACTIVITY TO 8073', CHANGE 5" HANDLING TOOLS TO 3.5", TRIP OUT WITH 3.5" DRILL PIPE, SERVICE RIG, PULL OUT OF THE HOLE AND LAY SUMMARY DOWN CORE BARREL, DRESS NEW CORE BARREL, SET ESS SURVEY TOOL, RUN IN THE HOLE WITH 3.5" DRILL PIPE, RUN IN THE HOLE WITH 5" DRILL PIPE, WASH FROM 14350 TO 14600', REAM FROM 14600' TO 14621', BEGIN CORE # 7 AT 14621' CORE #7. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORt FOR MAKE MURRAY DATE Apr 26, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 14674 YESTERDAY 14636 24 Hour Footage 38 PRESENT OPERATION= WORK ON RIG TOP DRIVE CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14562.64' INCLINATION 34.27 AZIMUTH VERTICAL DEPTH 125.76 11943.30 BIT INFORMATION NO. SIZE TYPE SIN 14rr3 6.75 DPI CMM35F 1963828 16 6.75 DPI CMM35F 1963878 DRILLING PARAMETERS RATE OF PENETRATION 28.7 SURFACE TORQUE 6884 WEIGHT ON BIT 11 ROTARY RPM 52 PUMP PRESSURE 2411 DRILLING MUD REPORT MW 9.5 VIS 73 PV FC \1 SOL 10.75 SD MWD SUMMARY INTERVAL TO TOOLS JETS 2X18,1X20 INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 14621 14674 53 6.7 3/4-1 PR 14674 0 HIGH @ 14646 @ 14641 @ 14656 @ 14674 @ 14642 DEPTH: 14645 19 YP OIL 2.9 5672 6 44 2333 LOW AVERAGE CURRENT AVG @ 14674 14.1 2.9 fi/hr @ 14674 6728.1 5672.1 amps @ 14668 9.6 10.9 Klbs @ 14641 48.9 52 RPM @ 14674 2444.1 2333 psi , 10 FL Gels 4/14/15 CL- 20000 76% MBL pH Ca+ CCI GAS SUMMARY(units) DITCH GAS CUq-~ING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH LOW AVERAGE 12 @ 14672 3 @ 14658 5.9 TRIP GAS= NN14674 0 @ 0 0 @ 0 0,0 WIPER GAS= 0 CHROMATOGRAPHY(ppi) SURVEY= 0 1720 @ 14672 248 @ 14658 611.1 CONNECTION GAS HIGH= 0 56 @ 14671 10 @ 14640 25.9 AVG= 0 29 @ 14671 3 @ 14655 9.8 CURRENT 0 32 @ 14674 5 @ 14666 4.3 CURRENT BACKGROUND/AVG 5 o @ o o @ o o HYDROCARBON SHOWS INTERVAL 14663TO14674 LITHOLOGY GOOD OIL STAIN IN CORE + C-4 FROM 14663 TO END OF CORE #7AT 14673' LITHOLOGY/REMARKS GAS DESCRIPTION SANDSTONE 70% CONGLOMERATE 30% BEFORE 4 70% SANDSTONE: ABNT LIGHT BROWN OIL STAIN ON CUTTINGS, MODERATE OCC POOR SORTING, NON TO DURING 12 SL TO MOD CRUMBLY W/TOUCH, GOOD VIS POROSITY AND SL CLAY MTX. END 10 PERMEABILITY, SL TO MOD PETRO ODOR FROM CUTTINGS. SANDSTONE, CONGLOMERATE, CONGLOMERATE SAND PRESENT LITHOLOGY 14660 TO 14674' = 70% SANDSTONE, 30% CONGLOMERATE DALLY ACTIVITY SUMMARY CORE TO 14674', PULL UP TO 14315', DROP DART AND PUMP DOWN DRY JOB, TRIP OUT WITH 5" DRILL PIPE AND CHANGE OUT 5" HANDLING TOOLS TO 3.5", TRIP OUT VV1TH 3.5" DRILL PIPE, LAY DOWN CORE BARREL AND BIT, SET ESS SURVEY AND PICK UP NEW CORE BARREL AND CORE BIT AND RUN IN THE HOLE WITH 3,5" DRILL PIPE, CIRCULATE MUD AND CHANGE OUT TO 5" HANDLING TOOLS, RUN IN THE HOLE TO THE SHOE, CUT AND SLIP 90' OF NEW DRILL LINE, CIRCULATE MUD AT THE SHOE AND BEGIN TO WORK ON THE TOP DRIVE. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 27, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14689 YESTERDAY 14674 24 Hour Footage 15 CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' EPOCH DEPTH SURVEY DATA 14689 PRESENT OPERATION= WiRE LINE LOGGING INCLINATION AZIMUTH VERTICAL DEPTH 12048.0 BIT INFORMATION NO, SIZE 16 6.75 TYPE DPI CMM35F DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE INTERVAL S/N JETS IN OUT 1963878 14674 14689 HIGH LOW 8.3 @ 14677 1,8 6257 @ 14681 2825 10 @ 14674 6 64 @ 14689 27 2439 @ 14677 2328 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 15 4.0 8/4-1 PR AVERAGE CURRENT AVG 14689 5.0 1,8 fi/hr 14675 6300.2 6015.3 amps 14676 9.5 10.0 Klbs 14675 57.5 64 RPM 14688 2535.1 2355 psi DRILLING MUD REPORT MW 9,5 VIS 9O FC /2 SOL 10,84 DEPTH: 14674' PV 21 YP 10 SD OIL 74,5% FL Gels 6/10/12 CL- MBL pH Ca+ 21000 CCI MWD SUMMARY . INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH 11 @ o @ METHANE(C-I) 1386 ETHANE(C-2) 48 PROPANE(C-3) 26 BUTANE(C-4) 32 PENTANE(C-5) 0 LOW AVERAGE 14674 5 @ 14675 4.4 o o @ o o CHROMATOGRAPHY(ppm) 14674 488 @ 14683 479.9 14674 29 @ 14678 25,9 14674 7 @ 14684 8.8 14674 1 @ 14683 3,1 o o @ o o TRIP GAS= 5 ! 14674' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 HYDROCARBON SHOWS INTERVAL SLIGHT SHOWOF C-4 AT 14674', NO SHOWAT 14675' . LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATE AND CONGLOMERATE SAND PRESENT LITHOLOGY 14674' - 14689' = 70% PEBBLE/GRAVEL CONGLOMERATE, 30% CONGLOMERATE SAND. DALLY ACTIVITY SUMMARY FINISH WORK ON TOP DRIVE, WASH AND REAM FROM 14566' TO 14674'. WIPE OUT TIGHT SPOTS AT 14644' AND 14655'. CORE FROM 14674' TO 14689', PULL UP TO 14284' WITH NO PROBLEMS, DROP DART AND PUMP DRY JOB, TRIP OUT WITH 5" DRILL PIPE, LAY DOWN ONE JOINT OF DRILL PIPE AND CHANGE OUT HANDLING TOOLS TO 3.5", PULL OUT OF THE HOLE WITH 3.5" DRILL PIPE, LAY DOWN CORE BARREL AND BREAK THE BIT OFF, STAND BACK CORE BARREL, CLEAN THE RIG FLOOR AND SERVICE THE RIG, RIG UP E-LINE AND PICK UP TOOLS, RUN IN THE HOLE WITH WIRE LINE LOGS. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F, BROWNE JR, FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 28, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 14725 YESTERDAY 14689 24 Hour Footage 36 PRESENT OPERATION= TRIP OUT TO SHOE CASING INFORMATION 9,625" @ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14727.2 BIT INFORMATION NO. SIZE 17 6.75 TYPE STC XR20DPGS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE INCLINATION AZIMUTH VERTICAL DEPTH 12079,3 INTERVAL CONDITION REASON SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED LY9624 2xl 8, lx20 14689 5,7 HIGH LOW AVERAGE CURRENT AVG 57,8 @ 14692 1,8 @ 14689 13,7 3.0 ft/hr 6015 @ 14689 SLIDE @ 14713 156.6 37,5 amps 33 @ 14724 2 @ 14692 21,3 29,4 Klbs 64 @ 14689 64 @ 14689 1.8 SLIDE RPM 3282 @ 14709 1768 @ 14690 2969,2 2756 psi DRILLING MUD REPORT MW 9.5 VIS FC \1 SOL MWD SUMMARY INTERVAL TOOLS TO DEPTH: 14689' 90 PV 20 YP 9 FL Gels 5/10/11 CL- 20000 10.7 SD OIL 74.5% MBL pH Ca+ CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 6 @ 14701 4 @ 14725 5.5 TRIP GAS= 7/14689' CUTTING GAS 0 @ 14725 0 @ 14725 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-I) 541 @ 14704 135 @ 14721 351.4 CONNECTION GAS HIGH= 0 ETHANE(C-2) 28 @ 14689 8 @ 14725 20.3 AVG= 0 PROPANE(C-3) 15 @ 14701 7 @ 14725 10.8 CURRENT 0 BUTANE(C-4) 9 @ 14700 1 @ 14691 2.0 CURRENT BACKGROUND/AVG 4 PENTANE(C-5) 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS NO HYDROCARBON SHOWS THE LAST 24 HRS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATE, CONGLOMERATE SAND, GRAPHITE (MUD ADDITIVE) PRESENT LITHOLOGY 14725' = 80% SAND, 10% CONGLOMERATE, 10% CONGLOMERATE SAND = ABNT GRINDING AND SHEARING OF CUTTINGS. RIG DOWN WIRE LINE EQUIPMENT, HOLD PRE JOB SAFETY MEETING, MAKE UP DRILLING ASSEMBLY AND RUN IN THE HOLE DAILY ACTIVITY WITH 3.5" DRILL PIPE, FILL PIPE WITH MUD AND CHANGE OVER TO 5" HANDLING TOOLS AT 4225', RUN IN THE HOLE WITH 5" SUMMARY DRILL PIPE TO 14312', CIRCULATE AND SH Epoch Personel EAR MUD, INSTALL BLOWER HOSE, RUN IN THE HOLE, "SLICK" AT 14312' - 14595', WASH AND REAM 94' TO BOTTOM, Daily On Board= CIRCULATE AND SHEAR MUD, STAGE UP PUMP RATE, BEGIN TO DRILL (SLIDE) FORMATION AT 14689'. Cost 2 Report by: $1773 FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DATE Apr 29, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14727 YESTERDAY 14725 24 Hour Footage 2 EPOCH PRESENT OPERATION= WORK ON TOP DRIVE CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' DEPTH INCLINATION AZIMUTH 14727 SURVEY DATA BIT INFORMATION NO. SIZE TYPE 17 6.75 STC XR20DPGS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE INTERVAL SIN JETS IN OUT LY9624 2X18, lX20 14689 HIGH LOW 8.6 @ 14727 1.2 @ 32 @ SLIDE 23 29 @ 14725 27 0 @ SLIDE 0 @ 3098 @ 14727 2756 @ FOOTAGE HOURS 5.7 AVERAGE 14726 6.4 SLIDE 47.8 14726 42.8 SLIDE 0.0 14725 4389.5 VERTICAL DEPTH 12079.3 CONDITION REASON T/B/C PULLED CURRENT AVG 8.6 fi/hr 23.8 amps 28.3 Klbs 0 RPM 3098 psi DRILLING MUD REPORT MW 9.5 VIS FC \1 SOL MWD SUMMARY INTERVAL TO TOOLS DEPTH: 14725' 82 PV 22 YP 10 FL Gels 11.26 SD OIL 74% MBL pH 6/11/12 CL- Ca+ 20000 CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 4 @ 14725 3 @ 14727 5.7 CUTTING GAS 0 @ 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 136 @ 14725 100 @ 14727 172.0 ETHANE(C-2) 8 @ 14725 5 @ 14727 9.5 PROPANE(C.3) 7 @ 14725 4 @ 14727 8.0 BUTANE(C-4) 0 @ 0 0 @ 0 0.0 PENTANE(C-5) 0 @ 0 0 @ 0 0.0 TRIP GAS-- 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 3 HYDROCARBON SHOWS NO HYDROCARBON SHOWS THE LAST 24 HRS INTERVAL LITHOLOGY/REMARKS LITHOLOGY 80% SAND, 10% CONGLOMERATE, 10% CONGLOMERATE SAND PRESENT LITHOLOGY 14727'= 80% SAND, 10% CONGLOMERATE, 10% CONGLOMERATE SAND GAS DESCRIPTION DALLY ACTIVITY SUMMARY DRILL TO 14727', PULL PIPE UP TO SHOE (14320'), CLEAN RIG FLOOR AND HOLD PRE JOB SAFETY MEETING, REMOVE TOP DRIVE TRACTION MOTOR AND DRAIN FLUIDS, DISCONNECT HYDRAULIC HOSES AND ELECTRICAL LINES, REMOVE FRONT OF PROTECTION GUARD AND TORQUE BOOST, LOOSEN BOLTS ON TRACTION MOTOR, REMOVE SPARK ARRESTER AND PREPARE TO UNPIN BLOCKS FROM THE TOP DRIVE, (CIRCULATING DRILLING MUD THROUGH THE CHOKE MANIFOLD WITH RETURNS TO THE PITS WITH THE ANNULAR CLOSED), CHANGE AND INSTALL ARMATURES AND BRUSHES, HOLD PRE JOB SAFETY MEETING, RIG AND SPOT CRANE, REINSTALL TOP DRIVE MOTOR, SERVICE THE RIG WITH VARIOUS FLUIDS. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE Apr 30, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14727 YESTERDAY 14727 24 Hour Footage 0 CASING INFORMATION 9.625"@ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14727' EPOCH PRESENT OPERATION= WORK ON TOP DRIVE MOTOR INCLINATION AZIMUTH VERTICAL DEPTH 12079' BIT INFORMATION NO. SIZE TYPE S/N 17 6.75 STC XR20DPGS LY9624 INTERVAL JETS IN OUT FOOTAGE HOURS 2X18, 1X20 14689 5.7 CONDITION REASON T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE HIGH LOW AVERAGE CURRENT AVG 0 @ 0 0 @ 0 0 0 ftJhr 0 @ 0 0 @ 0 0 0 amps 0 @ 0 0 @ 0 0 0 Klbs 0 @ 0 0 @ 0 0 0 RPM 0 @ 0 0 @ 0 0 0 psi DRILLING MUD REPORT MW 9.5 VIS FC \1 SOL 90 11.38 DEPTH: 14727' PV 20 YP 12 FL Gels SD OIL 74% MBL pH 7/11/12 CL- Ca+ 20000 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 3 @ CIRC 1 @ CIRC 2 CU'VI'ING GAS 0 @ 0 0 (~ 0 0 CHROMATOGRAPHY(ppm) METHANE(C-I) 0 @ 0 0 @ 0 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS NO HYDROCARBON SHOWS THE LAST 24 HRS. INTERVAL LITHOLOGY/REMARKS TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUN D/AVG 0 GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 14727' = 80% SAND, 10% CONGLOMERATE, 10% CONGLOMERATE SAND DALLY ACTIVITY SUMMARY FINISH INSTALLING THE TORQUE BOOST HOOK-UP, HYDRAULIC HOSES AND SPARK ARRESTOR, INSTALL FRONT PROTECTION GUARD, MAKE UP ELECTRICAL LINES, SAFETY WIRE ALL HEX BOLTS, INSTALL OIL, INSTALL BLOWER HOSE, BLEED OFF AIR, MAKE UP ELECTRICAL LINES, FUNCTION TEST OPENING OF TRACTION MOTOR AND TOP DRIVE, SET ARMATURE DRESSING BRUSHES, FOUND FLASHING AT THE BOTTOM OF ARMATURES, WAIT ON ORDERS, CIRCULATE DRILLING MUD, PREPARE FIRST MOTOR FOR SHIPPING, CLEAR FLOOR AND SECURE LOCK OUT-TAG OUT, BEGIN REMOVAL OF QUADS, SAFETY LINES, DRAIN GEAR BOX, DISCONNECT EQUIPMENT FOR ACCESS OF REMOVAL OF JUNK TRAC MOTOR, CHANGE OUT ARMATURES AND COMPONENTS, TRANSFER ACCESSORIES FOR FRESH MOTOR INSTALLATION, CIRC MUD AT 10-12 SPM. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 01,2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14727 YESTERDAY 14727 24 Hour Footage 0 EPOCH CASING INFORMATION 9.625"@ 9011' 7.625"@ 13420 DEPTH SURVEY DATA 14727' PRESENT OPERATION= WORK ON TOP DRIVE INCLINATION AZIMUTH VERTICAL DEPTH 12079.3' BIT INFORMATION NO. SIZE TYPE SIN 17 6.75 STC XR2ODPGS LY9624 INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2X18, 1X20 14689 5.7 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE H IG H LOW AVE RAG E CURRENT AVG 0 6 0 0 6 0 0 0 fi/hr 0 6 0 0 6 0 0 0 amps 0 6 0 0 6 0 0 0 Klbs 0 6 0 0 6 0 0 0 RPM 0 6 0 0 6 0 0 0 psi DRILLING MUD REPORT MW 9.5 VIS FC /1 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I-I'ING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 87 11.26 DEPTH: 14727' PV 20 YP YP11 FL Gels 7/11/12 CL- SD OIL 74% MBL pH Ca+ 20000 CCI HIGH LOW AVERAGE 3 6 CIRC 2 6 ClRC 2 TRIP GAS= 0 0 6 0 0 6 0 0 WIPER GAS=O CHROMATOGRAPHY(ppm) SURVEY= 0 0 6 0 0 6 0 0 CONNECTION GAS HIGH= 0 0 6 0 0 6 0 0 AVG= 0 0 6 0 0 6 0 0 CURRENT 0 0 6 0 0 6 0 0 CURRENT BACKGROUND/AVG 0 o 6 o o 6 o o NO HYDROCARBON SHOWS THE LAST 24 HRS LITHOLOGY/REMARKS GAS DESCRIPTION DAILY ACTIVITY SUMMARY LITHOLOGY PRESENT LITHOLOGY 14727'= 80% SAND, 10% CONGLOMERATE, 10% CONGLOMERATE SAND CONTINUE TO MONITOR WELL, PERIODICALLY CIRCULATING AT 10-13 SPM / 2-3 UNITS OF GAS, WORK ON TOP DRIVE: CHANGE OUT ARMATURES AND COMPONENTS, TRANSFERING ACCESSORIES, FINISH FRESH MOTOR INSTALLATION, PRE HEAT NEW PINION GEAR FOR INSTALLATION ON MOTOR DRIVE, RUN TEST TRACTION MOTOR AND SET BRUSHES, CHECK BEARINGS, HOLD PRE JOB SAFETY MEETING, PICK AND SPOT CRANE, STAB AND INSTALL MOTOR ON THE TOP DRIVE, CHECK AND SHIM GEAR LASH AND ALINGMENT PERIMETERS AND TOE IN, TORQUE MOUNTING BOLTS, INSTALL SAFETY WIRES AND KEEPERS, INSTALL TORQUE BOOST, SPARK ARRESTOR, HYDRAULIC AND ELECTRICAL LINES, FILL GEAR BOX, HOLD PRE JOB SAFETY MEETING AND INSTALL GUARDS, SPACERS AND KEEPERS, SAFERTY WIRE GEAR OIL, FILL BRAKE FLUIDS, DOUBLE CHECK FOR OVERHEAD TOOLS, CLEAN UP AND WIPE DOWN FOR LEAKS, INSPECT BRAKES AND LINKAGE, CUTAND SLIP DRILL LINE (38'), Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNiT #2 REPORT FOR DON JONES DATE May 02, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14800 YESTERDAY 14727 24 Hour Footage 73 CASING INFORMATION 9.675"@ 9011' 7.625"@ 14320' DEPTH SURVEY DATA 14800' EPOCH PRESENT OPERATION= PULL OUT w/BIT #17 TO CORE INCLINATION AZIMUTH VERTICAL DEPTH 12139.5' BIT INFORMATION NO. SIZE TYPE SIN 17 6.75 STC XR20DPGS LY9624 INTERVAL JETS IN 2X18,1X20 14689 CONDITION REASON OUT FOOTAGE HOURS T/B/C PULLED 14800 110' 17.2 NA CP DRILLING PARAMETERS HIGH RATE OF PENETRATION 36.9 @ 14768 3.2 SURFACE TORQUE 8025 @ 14768 5824 WEIGHT ON BIT 28 @ 14727 10 ROTARY RPM 83 @ 14744 64 PUMP PRESSURE 3146 @ 14731 2552 LOW AVERAGE CURRENT AVG @ 14729 12.1 5.5 fi/hr @ 14798 7010.8 6531,5 amps @ 14768 22,8 25.8 KIbs @ 14798 78,5 77 RPM @ 14798 3056.3 3022 psi DRILLING MUD REPORT MW 9.5 VIS 87 PV FC \1 SOL 11,26 SD MVVD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I=FING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH 20 @ o @ 3129 84 55 50 0 DEPTH: 14727' 20 YP 11 OIL 74% LOW AVERAGE 14750 3 @ 14727 10,0 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) 14747 100 @ 14727 1312.7 14747 5 @ 14727 43.4 14747 4 @ 14727 27.4 14774 2 @ 14729 19.6 o o @ o o.o FL Gels 7/11/12 CL- MBL pH Ca+ 20000 CCI TRIP GAS= 0 WIPER GAS= 14 / 14727' SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 HYDROCARBON SHOWS INTERVAL 14730' TO 14800' C4 NOTED FROM 14730' TO 14800' LITHOLOGY/REMARKS SAND 50% CONGLOMERATE 20% CONGLOMERATE SAND 30% GAS BEFORE 3 DURING 2O END 6 DESCRIPTION SAND/CONGLOMERATE SAND = VERY POORLY SORTED, MOD MED GRAIN SAND MATRIX, MOD SILTAND CLAY INFILL, ABNT BiT IMPCT FRAGS, OIL BASE MUD LITHOLOGY PRED CONGLOMERATE SAND AND SAND PRESENT LITHOLOGY 14800' = 30% SAND, 30% CONG SAND, 30% CONG, 10% SILT DAILY ACTIVITY SUMMARY FINISH MAKE UP OF TOP DRIVE ELECTRICAL LINES, BLEED AIR OFF TOP DRIVE BRAKES, INSTALL BLOWER HOSE, TEST FUNCTION OPERATION OF TRACTION MOTOR AND TOP DRIVE, REMOVE TORQUE BOOST AND CLEAN OUT BROKEN PISTON DOGS AND BEARINGS, WAIT ON PARTS, INSTALL NEW PISTON DOGS AND BEARINGS TO TORQUE BOOST AND INSTALL TOP DRIVE, FUNCTION TEST OPERATION OF THE TRACTION MOTOR AND TOP DRIVE, OK, RUN IN THE HOLE FROM THE SHOE AND WASH 35' TO BOTTOM, SLICK AND NO FILL, 14 UNITS OF WIPER GAS, DRILL FORMATION TO 14740' AND CIRCULATE OUT, DRILL AHEAD TO 14800' AND CIRCULATE OUT, PREPARE TO PULL OUT OF THE HOLE TO CORE. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR, FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE May 03, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14800 YESTERDAY 14800 24 Hour Footage 0 INCLINATION CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14800' EPOCH PRESENT OPERATION= INJECTION TESTING AZIMUTH VERTICAL DEPTH 12139.5' BIT INFORMATION NO. SIZE TYPE S/N JETS 17 6.75 STC XR20DPGS LY9624 2X18, lX20 DRILLING PARAMETERS HIGH RATE OF PENETRATION 0 @ 0 SURFACE TORQUE 0 @ 0 WEIGHT ON BIT 0 @ 0 0 ROTARY RPM 0 @ 0 0 PUMP PRESSURE 0 @ 0 0 DRILLING MUD REPORT DEPTH: 14800' MW 9.5 VIS 95 PV 21 YP FC \1 SOL 11.25 SD OIL INTERVAL IN 14689 LOW 0 @ 0 0 @ 0 @ 0 @ 0 @ 0 11 75% OUT 14800 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 110 17.2 6/8-E-1/2 CP AVERAGE CURRENT AVG 0 0 fi/hr 0 0 amps 0 0 Klbs 0 0 RPM 0 0 psi FL Gels 7/11/12 CL~ MBL pH Ca+ 20000 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS= 0 CUTTING GAS 0 @ 0 0 @ 0 0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-I) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH= 0 ETHANE(C-2) 0 @ 0 0 @ 0 0 AVG= 0 PROPANE(C-3) 0 @ 0 0 @ 0 0 CURRENT 0 BUTANE(C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS NO HYDROCARBON SHOWS THE LAST 24 HRS. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION DALLY ACTIVITY SUMMARY LITHOLOGY PRESENT LITHOLOGY 14800' = 30% CONGLOMERATE, 30% CONGLOMERATE SAND, 30% SAND, 10% SILT. DROP AND PUMP MULTI SHOT SURVEY DOWN THE HOLE, PULL OUT OF THE HOLE TO 14251', DROP BYPASS DART AND PUMP DOWN, PUMP DRY JOB, REMOVE TOP DRIVE BLOWER HOSE, MONITOR THE WELL, CLEAN EXCESS OIL BASE MUD FROM THE RIG FLOOR, TRIP OUT OF THE HOLE WITH 5" DRILL PIPE, CHANGE OUT 5" HANDLING TOOLS TO 3.5" AND TRIP OUT OF THE HOLE WITH 3.5" DRILL PIPE, PULL OUT OF THE HOLE WITH BHAAND LAY DOWN DRILLING ASSEMBLY, HOLD A PRE JOB SAFETY MEETING AND MAKE UP TEST JOINTS, CROSS OVERS AND PUMP SUB, PULL WEAR RING AND REVERSE DRESS AND SEAT PLUG, FILL THE STACK AND TEST HYDR 3.5" RAMS, BLINDS, MANUAL KILL, CHOKE, 5" RAMS AND MANUAL IBOPE, PULL PLUG AND SET WEAR RING, LAY DOWN TEST JOINTS, CLEAN THE RIG FLOOR, HOLD A PRE JOB SAFETY MEETING AND RIG UP WIRE LINE LOGS, LOG HOLE AND RIG DOWN WIRE LINE LOGS, HOLD A PRE JOB SAFETY MEETING AND START INJECTION TESTING OF CU'I-FINGS. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 04, 2001 TIME 04:00 DALLY WELLSITE REPORT DEPTH 14813 YESTERDAY 14800 24 Hour Footage 13 CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14718.12' INCLINATION 32.21 AZIMUTH 122.90 EPOCH PRESENT OPERATION= CORE # 9 VERTICAL DEPTH 12073.3 BIT INFORMATION NO. SIZE TYPE S/N 18 6.75 DPI CNR55 1963862 INTERVAL JETS IN OUT 14800 FOOTAGE HOURS 7.5 CONDITION REASON T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE VVEIGHT ON BIT ROTARY RPM PUMP PRESSURE 5.5 6760 25 77 3022 HIGH LOW @ 14800 0.6 @ 14813 @ 14803 3798 @ 14801 @ 14800 5 @ 14801 @ 14800 39 @ 14801 @ 14800 2206 @ 14811 AVERAGE CURRENT AVG 2.7 0.6 fi/hr 6941.8 6572.1 amps 9.0 8.2 Klbs 62.5 59 RPM 2500.7 2249 psi DRILLING MUD REPORT MW 9.5 VIS FC \1 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS 92 11.22 PV SD HIGH 0 @ DEPTH: 14812' 21 YP 11 FL OIL 74% MBL Gels pH 7/11/12 CL- 21000 Ca+ CCI METHANE(C-I) 488 @ ETHANE(C-2) 30 PROPANE(C-3) 15 @ BUTANE(C-4) 10 @ PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL , LOW AVERAGE 14800 2 @ 14809 2.8 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) 14800 127 @ 14807 182.9 14800 12 @ 14810 15.4 14800 6 @ 14810 8.3 14800 1 @ 14808 2.5 o 0 @ 0 0.0 TRIP GAS= 4 / 14800' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 3 NO HYDROCARBON SHOWS LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND AND CONGLOMERATE SAND PRESENT LITHOLOGY 14810' = 50% SAND 50% CONGLOMERATE SAND DALLY ACTIVITY SUMMARY RUN IN THE HOLE VV1TH WIRE LINE TEMP, LOG, FINISH LOGS AND PULL OUT OF THE HOLE, MAKE UP CORE ASSEMBLY #9 AND RUN IN THE HOLE, TRIP IN THE HOLE WITH 3.5" DRILL PIPE, MONITOR THE WELL AT 8077', BREAK CIRCULATION AND CHANGE OUT 3.5" HANDLING TOOLS TO 5", RUN IN THE HOLE WITH 5" DRILL PIPE, MONITOR THE WELL AT 11,100' AND 14252', WASH AND REAM TO BO'I-rOM 14320 TO 14800', BEGIN CORE #9. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 05, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14844 YESTERDAY 14813 24 Hour Footage 31 CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' DEPTH SURVEY DATA 14844' SIN JETS 1963862 BIT INFORMATION NO. SIZE 18 6.75 EPOCH TYPE DPI CNR55 PRESENT OPERATION= TRIP OUT W/CORE #9 INCLINATION AZIMUTH VERTICAL DEPTH 12180.3' INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 14800 14844 44 25.9 NA PR DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE HIGH LOW 5.1 @ 14833 0.6 @ 14813 6924 @ 14827 6532 @ 14814 13 @ 14844 7 @ 14815 59 @ 14813 57 @ 14823 2262 @ 14843 2133 @ 14822 AVERAGE C U RRENT AVG 2.5 0 ft/hr 7007.0 6749.0 amps 12,2 13.1 Klbs 59.9 59 RPM 2276.6 2258 psi DRILLING MUD REPORT MW 9.5 VIS FC \1 SOL 92 11.22 DEPTH: 14812' PV 21 YP 11 FL SD OIL 74% MBL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH LOW AVERAGE 5 @ 14818 2 @ 14837 3.6 0 @ 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) 358 @ 14826 111 @ 14823 172.2 38 @ 14818 10 @ 14831 17.6 13 @ 14818 3 @ 14831 6.4 7 @ 14818 I @ 14824 1.2 o @ o o @ o o Gels 7/11/12 CL- 21000 pH Ca+ CCI TRIP GAS= 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 HYDROCARBON SHOWS INTERVAL NO HYDROCARBON SHOWS THE LAST 24 HOURS LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATE SAND, CONGLOMERATE, SAND AND CLAY PRESENT LITHOLOGY 14835'= 50% CONGLOMERATE SAND, 20% CONGLOMERATE, 30% CLAY/SILT MIX DAILY ACTIVITY SUMMARY CORE TO 14844', MONITOR THE WELL, LAY DOWN PUP AND 2 SINGLES, TRIP OUTTO THE SHOE, MONITOR THE WELL, DROP DART AND PUMP DOWN, PUMP DRY JOB, REMOVE BLOWER HOSE, CLEAN RIG FLOOR AND BEGIN TO PULL OUT OF THE HOLE AT 12:15 AM. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP. REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 06, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14898 YESTERDAY 14844 24 Hour Footage 54 INCLINATION CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' DEPTH SURVEY DATA 14898' EPOCH PRESENT OPERATION= TRIP OUT W/CORE #10 AZIMUTH VERTICAL DEPTH 12225.7' BIT INFORMATION NO. SIZE TYPE SIN JETS IN 18 6.75 DPI CNR55 1963862 14800 19 6.75 DPI CMM35F 1963879 14844 DRILLING PARAMETERS HIGH RATE OF PENETRATION 24.1 @ 14849 SURFACE TORQUE 8185 @ 14885 WEIGHT ON BIT 13 @ 14844 ROTARY RPM 68 @ 14876 PUMP PRESSURE 2452 @ 14859 INTERVAL OUT 14844 14898 LOW 1.6 @ 3255 3 27 @ 2168 @ CONDITION REASON FOOTAGE HOURS T/B/C PULLED 44 25.9 5%/A-I PR 53 10.1 NA PR AVERAGE CURRENT AVG 14898 8.8 1,4 ft/hr 14865 7465.5 6802.5 amps 14847 8.5 12.0 Klbs 14865 63.8 68 RPM 14845 2401.7 2370 psi DRILLING MUD REPORT DEPTH: 14894' MW 9.5 VIS 91 PV 21 YP FC \1 SOL 12 SD OIL MVVD SUMMARY INTERVAL TO TOOLS 13 75% FL Gels 7/11/12 CL- MBL pH Ca+ 19000 CCI GAS SUMMARY(units) HIGH DITCH GAS 5 @ CUTTING GAS 0 @ METHANE(C-I) 406 @ ETHANE(C-2) 19 PROPANE(C-3) 11 @ BUTANE(C-4) 3 @ PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL LOW AVERAGE 14879 2 @ 14852 3.6 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) 14877 106 @ 14852 181.6 14868 7 @ 14850 12.2 14877 3 @ 14868 5.4 14880 1 @ 14881 0.1 o o @ o o.o TRIP GAS= 5 / 14844' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 4 SLIGHT OIL STAIN IN CORE FROM 14836' - 14810'. WAXY BITUMEN FROM 14827 - 14830'. LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, CONGLOMERATE SAND, CONGLOMERATE, SILTSTONE PRESENT LITHOLOGY 14890' = 20% CONGLOMERATE, 20% SAND, 30% SILT, 30% CARBONACEOUS SHALE AND SILT. DALLY ACTIVITY SUMMARY PULL OUT OF THE HOLE WITH CORE #9, LAY DOWN BHA AND HOLD PRE JOB SAFETY MEETING, LAY DOWN THE CORE AND MAKE UP NEW CORE BARREL AND SURVEY TOOL, MAKE UP NEW BHA AND RUN IN THE HOLE TO 9000', SERVICE THE RIG, RUN IN THE HOLE TO 14260', MONITOR THE WELL, RUN IN THE HOLE TO 14750', WASH AND REAM TO BOTTOM MONITOR THE WELL AND CIRCULATE AND SHEAR THE MUD, BEGIN CORE #10 AT 14844' Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 07, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 14912 YESTERDAY 14898 24 Hour Footage 14 PRESENT OPERATION= TRIP OUT W/CORE #11 CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' DEPTH INCLINATION AZIMUTH 14912.3' SURVEY DATA VERTICAL DEPTH 12237.6' BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE 19 6.75 DPI CMM35F 1963879 14844 14898 53 20 6.75 DPI CMM35F 1963890 14898 14512 14 DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 6.1 @ 14905 1.6 @ 14898 SURFACE TORQUE 7241 @ 14906 1089 @ 14905 WEIGHT ON BIT 27 @ 14905 6 @ 14906 ROTARY RPM 68 @ 14898 10 @ 14905 PUMP PRESSURE 2389 @ 14911 1507 @ 14905 CONDITION REASON HOURS T/B/C PULLED 10.1 2/4-X-I PR 3.8 NA PR AVERAGE CURRENT AVG 3.7 1.8 ft/hr 4080.4 6836.9 amps 16.3 9.6 Klbs 34.6 60 RPM 1428.0 2317 psi DRILLING MUD REPORT DEPTH: 14912' MW 9.5 VIS 98 PV 22 YP 12 FL FC \1 SOL 11.3 SD OIL 75% MBL Gels 7/11/12 CL- 19000 pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 14888' HIGH LOW AVERAGE 8 @ 14904 5 @ 14898 5.5 TRIP GAS= 8/14898 0 @ o 0 @ 0 0,0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 892 @ 14904 51 @ 14898 473.6 CONNECTION GAS HIGH= 0 52 @ 14900 3 @ 14898 29.1 AVG= 0 20 @ 149O4 1 @ 14899 9.2 CURRENT 0 13 @ 14904 3 @ 14907 4,4 CURRENT BACKGROUND/AVG 0 o @ o o @ o o HEAVY OIL STAIN AT 14888' IN CORE CHIPS, NO C-4 NOTED LITHOLOGY/REMARKS GAS DESCRIPTION SANDSTONE 100% BEFORE 5 DURING MEDIUM TO FINE GRAIN FRIABLE SAND WITH GOOD POROSITY AND 8 AFTER 5 PERMEABILITY, VIS FLOR AND OIL STAIN, VERY SLIGHT PETRO ODOR. LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY 14844-14870' = 100% CONGLOMERATE SAND (VERY COARSE), 14870-14885' = TUFFACEOUS SILT, CARBONACEOUS SHALE AND COAL. 14885-14888' SANDSTONE GRADING TO CONGLOMERATE SAND, cORE HOLE TO 14898', MONITOR THE WELLi SURVEY AND PULL OUTTO 14240', DROP DARTAND PUMP DRY JOB, PULL OUT OF THE HOLE, HOLD PRE JOB SAFETY MEETING AND LAY DOWN THE CORE BARREL, MAKE UP NEW CORE BARREL, LOAD SURVEY TOOL, RUN iN THE HOLE WITH BHA AND DRILL PIPE TO 8800', HOLD BOP DRILL AND PRE JOB SAFETY MEETING, CUT AND SLIP 104' OF NEW DRILL LINE, RUN IN THE HOLE TO 14252', MONITOR THE WELL AND CIRCULATE AND SHEAR MUD, RUN IN THE HOLE TO 14795', WASH AND REAM TO BOTTOM, BEGIN CORE AT 14898 AND FINISH AT 14912', CIRCULATE AND MONITOR THE WELL, BEGIN TO PULL OUT OF THE HOLE WITH CORE #11. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 08, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14918 YESTERDAY 14912 24 Hour Footage 6 CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' EPOCH PRESENT OPERATION= CORE #12 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 14918' 12246' BIT INFORMATION NO. SIZE 20 6.75 18rrl 6.75 INTERVAL CONDITION RF_.ASON TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DPI CMM35F 1963890 14898 14912 14 3.8 2/4-X-I PR DPI CNR55 1963862 14912 7.4 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.5 ViS FC \1 SOL MWD SUMMARY INTERVAL TO TOOLS HIGH LOW AVERAGE CURRENT AVG 2.2 @ 14916 1.0 @ 14914 1,8 1.1 ft/hr 6836 @ 14912 6585 @ 14918 7838.9 6585.8 amps 11 @ 14918 8 @ 14913 12.0 11.8 Klbs 65 @ 14913 60 @ 14912 74.7 65 RPM 2375 @ 14914 2317 @ 14912 2743.2 2370 psi DEPTH: 14920' 97 PV 21 YP 12 FL Gels 7/11/12 CL- 11.33 SD OIL 76% MBL pH Ca+ 18000 CCI GaS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 4 @ 14916 3 @ 14918 4,3 TRIP GAS= 6/14912' CUTTING GAS 0 @ 0 0 @ 0 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-I) 347 @ 14916 178 @ 14918 306.0 CONNECTION GAS HIGH= 0 ETHANE(C-2) 33 @ 14916 14 @ 14916 27,7 AVG= 0 PROPANE(C-3) 15 @ 14912 6 @ 14915 12.3 CURRENT 0 BUTANE(C-4) 0 @ 0 0 @ 0 0.0 CURRENT BACKGROUND/AVG 4 PENTANE(C-5) 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS NO C-4 NOTED THE LAST 24 HRS/SAMPLE FLOR IN CORE #11 POSS, OIL BASE MUD CONTAMINATION. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PEBBLE CONGLOMERATE PRESENT LITHOLOGY 14915' = SAND 50%, CONGLOMERATE 50% ABNT BIT IMPACTED FRAGMENTS PULL OFF BO'I-I'OM WITH CORE #11 TO THE SHOE, DROP DART, PUMP DRY JOB, MONITOR THE WELL, PULL OUT OF THE HOLE AND LAY DOWN BHA AND HOLD A PRE JOB SAFETY MEETING, LAY DOWN CORE #11, PICK UP CORE BARREL #12, CHANGE OUT THE BIT AND ORIENTATE THE NEW CORE BARREL, SERVICE THE TOP DRIVE = DRAIN GEAR OIL AND CHECK BEARINGS, MAKE UP BHA AND DAILY RUN IN THE HOLE WITH DRILL COLLARS AND HWDP, RUN IN THE HOLE WITH 3.5" DRILL PIPE TO 8710', MONITOR THE WELL AND ACTIVITY CIRCULATE DRILL MUD, INSTALL AIR SLIPS AND CHANGE OUT TOP DRIVE LUBE FILTER, RUN IN THE HOLE WITH 5" DRILL PIPE TO SUMMARY 14250', MONITOR THE WELL AND CIRCULATE TO SHEAR DRILL MUD, WASH AND REAM TO BOTTOM (95'), TOP DRIVE MAKING NOISE=PULL BACK INTO CASING TO ADDRESS THE PROBLEM, REMOVE TOP DRIVE TORQUE BOOST DRIVE GEAR AND SHEAR AND REINSTALL MOTOR, RUN IN THE HOLE TO BOTTOM AND BEGIN CORING #12 FROM 14912'. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR, FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE May 09, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14934 YESTERDAY 14918 24 Hour Footage 16 CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' EPOCH PRESENT OPERATION= TRIP IN w/CORE #13 DEPTH SURVEY DATA 14934' INCLINATION AZIMUTH VERTICAL DEPTH 12256' BIT INFORMATION NO. SIZE TYPE SIN 18rrl 6.75 DPI CNR55 1963862 21 6,75 DPI CMM35F 1963891 JETS INTERVAL IN 14912 14934 OUT 14934 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 22 16.5 2/5-X-1 PR DRILLING PARAMETERS RATE OF PENETRATION 3.0 SURFACE TORQUE 6896 VVEIGHT ON BIT 14 ROTARY RPM 68 PUMP PRESSURE 2418 DRILLING MUD REPORT MW 9.5 VIS 97 PV FC \1 SOL 11.33 SD HIGH @ 14929 0.9 @ 14925 6444 @ 14927 11 @ 14932 59 @ 14934 2277 DEPTH: 14920' 21 YP OIL 12 76% LOW AVERAGE CURRENTAVG 14932 1.8 1.0 Whr 14932 7060.9 6500.7 amps 14919 14.5 14,4 Klbs 14923 69.4 68 RPM 14927 2474.6 2418 psi FL Gels 7/11/12 CL- MBL pH Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH DITCH GAS 5 @ CUTTING GAS 0 @ METHANE(C.1) 440 @ ETHANE(C-2) 42 @ PROPANE(C-3) 13 @ BUTANE(C-4) 7 @ PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL LOW AVERAGE 14924 3 @ 14934 4.3 o o @ o o.o CHROMATOGRAPHY(ppm) 14924 157 @ 14934 264.9 14926 12 @ 14934 22.4 14925 4 @ 14934 8.4 14924 2 @ 14923 0.8 o o @ o o 18000 TRIP GAS= NA/14934' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 HEAVY DARK BROWN BITUMEN LAYER AT 14912, NO C-4 NOTED LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PEBBLE CONGLOMERATE PRESENT LITHOLOGY PEBBLE CONGLOMERATE FROM 14912' TO 14934' DALLY ACTIVITY SUMMARY CCI CORE TO 14934', BREAK OFF CORE AFTER VERY SLOW ROP, MONITOR THE WELL, PULL BACK BIT INTO CASING, DROP DART, PUMP AND OPEN PORTS, DRY JOB, BLOWER HOSE OFF AND AIR SLIPS, PULL OUT OF THE HOLE TO 6077', MONITOR THE WELL AND CHANGE HANDLING TOOLS TO 3.5" AND CONTINUE TO PULL OUT OF THE HOLE, lAY DOWN CORE BARREL AND MAKE UP NEW CORE BARREL, CHANGE THRUST BEARING AND ORIENTATE THE SHOE, ORIENTATE AND LOAD SURVEY TOOL AND MONITOR THE WELL, RUN IN THE HOLE WITH BIT #21 TO CORE #13. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE May 10, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 14968 YESTERDAY 14934 24 Hour Footage 34 CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320 EPOCH PRESENT OPERATION= TEST BOP DEPTH SURVEY DATA 14968' INCLINATION AZIMUTH VERTICAL DEPTH 12284.8 BIT INFORMATION NO. SIZE TYPE SIN 21 6.75 DPI CMM35F 1963891 NA DRILLING PARAMETERS RATE OF PENETRATION 14.8 SURFACE TORQUE 7276 WEIGHT ON BIT 16 ROTARY RPM 68 PUMP PRESSURE 2418 DRILLING MUD REPORT MW 9.5 VIS 85 PV FO \1 SOL 11.06 SD MWD SUMMARY INTERVAL TO TOOLS INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 14934 14968 34 6.5 NA PR HIGH LOW AVERAGE CURRENT AVG @ 14937 0.6 @ 14935 7.0 1.6 fi/hr @ 14950 4801 @ 14935 7207,1 6944.4 amps @ 14935 4 @ 14936 6.1 6.1 Klbs @ 14934 39 @ 14937 49.9 54 RPM @ 14934 2152 @ 14935 2414.2 2334 psi DEPTH: 14968' 22 YP 13 FL Gels 8/12/13 CL- 25000 OIL 73% MBL pH Ca+ CCI GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH LOW AVERAGE 5 @ 14956 1 @ 14954 3.6 TRIP GAS= 5 / 14934 0 @ 14968 0 @ 14968 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 662 @ 14939 157 @ 14934 396.8 CONNECTION GAS HIGH= 0 23 @ 14938 9 @ 14965 15.7 AVG= 0 13 @ 14938 2 @ 14954 7,1 CURRENT 0 22 @ 14937 2 @ 14946 3.6 CURRENT BAOKGROUND/AVG 0 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS INTERVAL 14959 TO 14962' LITHOLOGY GOOD LIGHT BROWN OIL STAIN IN CORE #13 14959' TO 14962' LITHOLOGY/REM~ARKS GAS DESCRIPTION 100% SANDSTONE NOT CIRC UP: SANDSTONE = COARSE UPPER TO MEDIUM LOWER; SBRD; MOD CCC POORLY LOGGED AFTER SORTED; SL TO MOD KAOL MTX; CRUMBLY TENACITY OF SANDS; FAIR TO GOOD TRIP PORO & PERM; GOOD EVEN OIL STAIN W/SL PTERO ODOR. SANDSTONE, CONGLOMERATE SAND., CONGLOMERATE GRAVEL PRESENT LITHOLOGY 14968' 80% CONGLOMERATE 20% CONGLOMERATE SAND DALLY ACTIVITY SUMMARY RUN IN THE HOLE WITH CORE #13 TO 8100', CIRCULATE DRILLING MUD, RUN IN THE HOLE TO 14260' AND CIRCULATE DRILL MUD, HOLD PRE JOB SAFETY MEETING AND CUTAND SLIP DRILL LINE, SERVICE RIG, INSTALL BLOWER HOSE AND WORK ON TOP DRIVE, RUN IN THE HOLE TO BOTTOM AND CORE FROM 14935' TO 14968', MONITOR THE WELL AND PULL DRILL PIPE INTO THE CASING, DROP DART, CIRCULATE DRILLING MUD AND OPEN PORTS, MONITOR THE WELL, PUMP DRY JOB, REMOVE BLOWER HOSE, PULL OUT OF THE HOLE WITH 5" DRILL PIPE TO 8077', MONITOR THE WELL, CHANGE OUT 5" HANDLING TOOLS TO 3.5" AND CONTINUE TO PULL OUT OF THE WELL, PULL SURVEY TOOL AND LAY DOWN CORE BARREL #13. Epoch Personel On Board= 2 Report by: LEES F. BROWNE JR. Daily Cost $1773 FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE May 11,2001 TIME 19:45:20 DAILY WELLSITE REPORT DEPTH 14978 YESTERDAY 14968 24 Hour Footage 10 JETS CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' DEPTH SURVEY DATA 14978' BIT INFORMATION NO. SIZE TYPE SIN 21 6.75 DPI CMM35F 1963891 13rr2 6.75 DPI CMM35F 1963827 INCLINATION INTERVAL IN OUT 14934 14968 14968 14978 EPOCH PRESENT OPERATION= TRIP OUT WITH CORE #14 AZIMUTH VERTICAL DEPTH 12293.4 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 34 6.5 3/3-X-I PR 10 5.8 NA PR DRILLING PARAMETERS RATE OF PENETRATION 2,4 SURFACE TORQUE 7023 WEIGHT ON BIT 20 ROTARY RPM 60 PUMP PRESSURE 2504 DRILLING MUD REPORT MW 9.5 VIS 85 PV FC \1 SOL 11.06 SD HIGH @ 14975 @ 14971 @ 14969 @ 14976 @ 14978 DEPTH: 14968 22 YP OIL LOW 1.3 2396 5 17 @ 1654 @ 13 73% AVERAGE CURRENT AVG 14978 2.0 1.3 14969 7160.5 6704.3 14970 9.O 9.5 14969 55.7 6O 14969 2570,8 2504 FL Gels 8/12/13 CL- 25000 MBL pH Ca+ fi/hr amps Klbs RPM psi CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH DITCH GAS 3 CUTTING GAS 0 METHANE(C-I) 345 @ ETHANE(C-2) 12 PROPANE(C-3) 7 BUTANE(C-4) 13 @ PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY PEBBLE CONGLOMERATE LOW AVERAGE 14970 2 @ 14975 2.1 o o @ o o CHROMATOGRAPHY(ppm) 14968 157 @ 14972 160.4 14974 8 @ 14972 7.3 14970 4 @ 14973 3.7 14974 4 @ 14969 4.7 o o @ o o.o TRACE SHOW OF C-4 @ 14974' LITHOLOGY/REMARKS PRESENT LITHOLOGY 50% PEBBLE CONGLOMERATE, 50% CONGLOMERATE SAND TRIP GAS= 8 / 14968' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION DALLY ACTIVITY SUMMARY HOLD A PRE JOB SAFETY MEETING, LAY DOWN CORE BARREL #13, TEST BOP, INSTALL WEAR RING, MAKE UP NEW CORE BARREL AND BIT, ORIENTATE SURVEY TOOL, RUN IN THE HOLE TO 8100', CIRCULATE DRILLING MUD, RUN IN THE HOLE TO 14250' AND CIRCULATE MUD AND MONITOR THE WELL, SERVICE THE RIGS TOP DRIVE, SHEAR THE DRILLING MUD, WASH AND REAM 60' TO BOTTOM, CORE FROM 14968 TO 14978', MONITOR THE WELL AND PULL BACK TO CASING, DROP DART, PUMP AND OPEN PORTS, PUMP DRY JOB, BEGIN TO PULL OUT OF THE HOLE WITH CORE #14. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE May 12, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 15000 YESTERDAY 14978 24 Hour Footage 22 CASING INFORMATION 9.625" @ 9011' 7.625"@ 14320' DEPTH SURVEY DATA 15000' INCLINATION EPOCH PRESENT OPERATION= TRIP OUT w/CORE #15 AZIMUTH VERTICAL DEPTH 12311.1' BIT INFORMATION NO. SIZE TYPE SIN 13rr2 6.75 DPI CMM35F 1963827 22 6.75 DPI CMM35F 1963901 JETS INTERVAL IN OUT 14968 14978 14978 150OO FO OTAG E 10 22 DRILLING PARAMETERS RATE OF PENETRATION 10.7 SURFACE TORQUE 7626 WEIGHT ON BIT 9 ROTARY RPM 79 PUMP PRESSURE 2504 HIGH LOW @ 14981 1.3 @ 15000 @ 14994 6258 @ 14979 @ 14978 2 @ 14979 @ 14990 34 @ 14979 @ 14978 2054 @ 14979 DRILLING MUD REPORT MW 9.5 VIS 100 PV FC \1 SOL 10.92 SD DEPTH: 14978' 24 YP 18 FL OIL 73% MBL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 14979 TO 14982 HIGH 4 o @ 424 @ 22 @ 7 @ 17 @ 14 @ LOW AVERAGE 14979 2 @ 14978 2.4 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) 14980 100 @ 14992 165,9 14979 9 @ 14989 9.6 14979 1 @ 14992 3.0 14980 2 @ 14991 3.5 14982 1 @ 14986 2.1 TRACE C-4 AND C-5 @ 14979' TO 14982' LITHOLOGY/REMARKS NA - CORE IS NOT OUT OF THE HOLE. LITHOLOGY CARBONACEOUS SHALE AND SILT, SAND Gels pH GAS BEFORE 3 DURING 4 AFTER 2.5 PRESENT LITHOLOGY 14992' = VERY POOR SAMPLE QUALITY, CARB SHALE AND SILT WITH SANDS DALLY ACTIVITY SUMMARY CONDITION REASON HOURS T/B/C PULLED 5.8 2/2-X-I PR 6.8 NA PR AVERAGE CURRENT AVG 4.5 1.3 ftJhr 7576.2 6935.0 amps 6.2 7.1 Klbs 75.8 79 RPM 2395.5 2366 psi 10/15/16 CL- 28000 Ca+ CCI TRIP GAS= 5 / 14978' WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 DESCRIPTION TRACE AMOUNTS OF C-4 AN D C-5. PUll OUT OF THE' HOLE WITH CORE #14, HOLD A PRE JOB SAFETY MEETING AND LAY DOWN THE CORE BARREL, CHANGE OUT THE SURVEY TOOL AND ORIENTATE NEW SURVEY TOOL, CHANGE OUT THE CORE BIT, RUN IN THE HOLE TO 8100', CIRCULATE THE DRILLING MUD, RUN IN THE HOLE TO 14250' AND CIRCULATE THE DRILLING MUD, CHANHE OIL IN TOP DRIVE AND SERVICE THE RIG, RUN IN THE HOLE TO 14911' AND WASH AND REAM TO THE BOTTOM OF THE HOLE (14978'), NO FILL NOTED, CORE FROM 14978' TO 15000', PULL OUT OF THE HOLE TO THE SHOE, PULLED TIGHT JUST BELOWTHE SHOE, DROP DART AND SHEAR CIRCULATING SUB, PUMP DRY JOB, MONITOR THE WELL AND BEGIN TO PULL OUT OF THE HOLE WITH CORE #15. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST Oil CORP REDOUBT UNIT #2 REPORT FOR MIKE MURRAY DATE May 13, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 15047 YESTERDAY 15000 24 Hour Footage 47 EPOCH CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' DEPTH SURVEY DATA 15047' PRESENT OPERATION= TRIP OUT w/CORE #16 INCLINATION AZIMUTH VERTICAL DEPTH 12353.0' BIT INFORMATION NO. SIZE TYPE SIN 22 6.75 DPI CMM35F 1963901 22rrl 6.75 DPI CMM35F 1963901 DRILLING PARAMETERS RATE OF PENETRATION 14.6 SURFACE TORQUE 7657 WEIGHT ON BiT 7 ROTARY RPM 79 PUMP PRESSURE 2411 DRILLING MUD REPOi~'I' MW 9.5 ViS 87 PV FO \1 SOL 10.42 SD MWD SUMMARY INTERVAL TO TOOLS INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 14978 15000 22 6.8 1/2-X-I PR 15000 15047 47 10.3 NA PR HIGH LOW AVERAGE CURRENT AVG @ 15017 1.3 @ 15000 6.2 2.7 fi/hr @ 15018 6772 @ 15001 7502.6 6965.1 amps @ 15046 1 @ 15001 5.3 7.8 Klbs @ 15000 52 @ 15001 56.3 56 RPM @ 15001 2239 @ 15044 2380.0 2331 psi DEPTH: 15038' 22 YP 13 FL Gels 7/11/12 CL- 28000 OIL 73.5% MBL pH Ca+ CCI GAS SUMMARY(units) HIGH DITCH GAS 6 CUTTING GAS 0 @ METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C.5) HYDROCARBON SHOWS INTERVAL LITHOLOGY SAND PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY LOW AVERAGE 15025 3 @ 15006 3.6 TRIP GAS= 4/15000 0 0 @ 0 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 422 @ 15023 126 @ 15000 205.7 CONNECTION GAS HIGH= 0 31 @ 15033 4 @ 15000 12,0 AVG= 0 12 @ 15033 3 @ 15035 4.3 CURRENT 0 3 @ 15023 1 @ 15024 0.2 CURRENT BACKGROUND/AVG 5 o @ o o @ o o.o NO SHOW OF C-4 OR C-5 IN CORE #16 LITHOLOGY/REMARKS 15035': 30% SAND, 70% GRAPHITE MUD ADDITIVE ADDITIVE GAS DESCRIPTION PULL OUT OF THE HOLE WITH CORE #15, HOLD A PRE JOB SAFETY MEETING, REMOVE THE SURVEY TOOL, LAY DOWN THE CORE BARREL, MAKE UP A NEW CORE BARREL, ORIENTATE THE SURVEY TOOL, BREAK BIT AND INSPECT, HOLD A PRE JOB SAFETY MEETING, PICK UP SURVEY TOOL, MAKE UP BHA, RUN IN THE HOLE TO 8150', CIRCULATE DRILLING MUD, RUN IN THE HOLE TO 14320', CUT AND SLIP DRILL LINE (320'), SERVICE THE RIG, INSPECT CROWN AND BLOCK SHEEVES, RUN IN THE HOLE AND REAM THE LAST 25', BEGIN CORE # 16 @ 15,000', CORETO 15047', Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIt #2 REPORT FOR MIKE MURRAY DATE May 14, 2001 TIME 04:00 DALLY WELLSITE REPORT EPOCH DEPTH 15060 YESTERDAY 15047 24 Hour Footage 13 PRESENT OPERATION= TRIP OUT W/CORE #16 CASING INFORMATION 9.625" @ 9011° 7.625" @ 14320' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 15060' 12364' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 22rrl 6.75 DPI CMM35F 1963901 15000 15047 47 10.3 1/4-X-I PR 23 6.75 DPI CMM35F 1963902 15047 15060 13 3.8 NA PR DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 12.2 @ 15048 1.0 @ 15060 5.7 1.0 fi/hr SURFACE TORQUE 7148 @ 15051 5787 @ 15048 7306.1 6540.0 amps WEIGHT ON BIT 8 @ 15060 2 @ 15047 6.1 8.0 Klbs ROTARY RPM 59 @ 15060 21 @ 15047 57.4 59 RPM PUMP PRESSURE 2462 @ 15057 1800 @ 15047 2472,6 2432 psi DRILLING MUD REPORT DEPTH: 15059' MW 9.5 VIS 94 PV 23 YP 14 FL Gels 7/11/12 CL- 30000 FC \1 SOL 10.84 SD OIL 72% MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 9 @ 15049 4 @ 15055 5.2 CUTTING GAS 0 @ 0 0 @ 0 0 CHROMATOGRAPHY(ppm) METHANE(C-I) 807 @ 15049 182 @ 15055 316.2 ETHANE(C-2) 40 @ 15049 10 @ 15055 17.0 PROPANE(C-3) 15 @ 15049 4 @ 15055 5.7 BUTANE(C-4) 3 @ 15049 1 @ 15050 0.4 PENTANE(C~5) 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS TRACE SHOW OF C-4 IN CORE #16 INTERVAL LITHOLOGY/REMARKS LITHOLOGY SAND PRESENT LITHOLOGY 15055' 60% SAND, 30% CONGLOMERATE, 10% GRAPHITE (MUD ADDITIVE) DALLY ACTIVITY SUMMARY TRIP GAS= 8/14047 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION CORE TO 15047', SURVEY, MONITOR THE WELL, PULL OUT OF THE HOLE TO 14200', DROP DART, PUMP DRY JOB, PULL OUT OF THE HOLE, LAY DOWN SURVEY TOOL, HOLD A PRE JOB SAFETY MEETING, LAY DOWN THE CORE, PICK UP CORE NEW CORE BARREL, CHANGE OUT BIT, RUN IN THE HOLE WITH BHA, HOLD A BOP DRILL, CLEAN THE RIG FLOOR, SERVICE THE RIG, RUN IN THE HOLE WITH 3.5" DRILL PIPE, CHANGE OVER TO 5" DRILL PIPE AND CONTINUE TO RUN INTO THE HOLE TO 14320', CIRCULATE DRILL MUD, RUN IN THE HOLE TO 14925', CIRCULATE DRILLING MUD, REAM FROM 15020' TO 15047', NO FILL, CORE #16 FROM 15047' TO 15060'. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 15, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 15088 YESTERDAY 15060 24 Hour Footage 28 EPOCH PRESENT OPERATION= TRIP OUT W/CORE #18 CASING INFORMATION 9.625"@ 9011' 7.625"@ 14320' DEPTH INCLINATION AZIMUTH 15088' SURVEY DATA VERTICAL DEPTH 12387.6' BIT INFORMATION NO. SIZE TYPE 23 6.75 DPI CMM35F 23rrl 6.75 DPI CMM35F DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE INTERVAL CONDITION SIN JETS IN OUT FOOTAGE HOURS T/B/C 1963902 15047 15060 13 3.8 1/2-X-I 1963902 15060 15088 28 8.4 NA HIGH LOW AVERAGE CURRENT AVG 7.0 @ 15075 1.0 @ 15062 4.0 0.0 7440 @ 15064 3696 @ 15061 7265.2 6141.3 8 @ 15063 5 @ 15084 7.2 7.7 80 @ 15087 30 @ 15061 76.9 57 2496 @ 15063 2052 @ 15061 2456.1 2362 REASON PULLED PR PR ft/hr amps Klbs RPM psi DRILLING MUD REPORT MW 9.5 VIS 90 FC \1 SOL 10.86 MWD SUMMARY INTERVAL TO TOOLS DEPTH: 15078' PV 24 YP 12 FL Gels 7/11/12 CL- SD OIL 10.86 MBL pH Ca+ 29000 CCI GAS SUMMARY(units) DITCH GAS CU'I-['ING GAS - METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HIGH LOW AVERAGE 9 @ 15062 4 @ 15060 5.2 TRIP GAS= 8 / 14060' 0 @ 0 0 @ 0 0.0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 793 @ 15062 161 @ 15060 240.9 CONNECTION GAS HIGH= 0 28 @ 15070 10 @ 15081 13,7 AVG= 0 13 @ 15061 4 @ 15076 6.3 CURRENT 0 4 @ 15062 1 @ 15063 0.2 CURRENT BACKGROUND/AVG 6 o @ o o @ o o.o HYDROCARBON SHOWS INTERVAL NO SHOWS OF C-4 OR C-5DRLLLING CORE #18 LITHOLOGY/REMARKS GAS LITHOLOGY COAL, SAND, CONGLOMERATE SAND, SILT PRESENT LITHOLOGY 15080'= 20% COAL (POSS CVGS), 30% SILT, 50% SAND, 0-20% CONGLOMERATE SAND DESCRIPTION DALLY ACTIVITY SUMMARY SURVEY HOLE, MONITOR THE WELL, PULL OUT OF THE HOLE TO 14239', DROP DART, PUMP DRY JOB, PULL OUT OF THE HOLE AND HOLD A PRE JOB SAFETY MEETING, LAY DOWN THE SURVEY TOOL AND CORE BARREL, PICK UP THE NEW CORE BARREL AND ORIENTATE THE SURVEY TOOL, CHECK THE BIT, SERVICE THE RIG, RUN IN THE HOLE WITH 3.5" DRILL PIPE, CIRCULATE DRILL MUD AT 8100', CHANGE OVER TO 5" HANDLING TOOLS AND RUN IN THE HOLE WITH 5" DRILL PIPE TO THE SHOE, CUT AND SLIP 75' OF DRILL LINE AND HOLD A PRE JOB SAFETY MEETING, RUN IN THE HOLE AND CIRCULATE FROM 14942 TO 15036', WASH AND REAM FROM 15036' TO 15060', BEGIN TO CORE FROM 15060' TO 15088', PREP TO PULL OUT OF THE HOLE WITH CORE #18. Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 16, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 15088 YESTERDAY 15088 24 Hour Footage 0 INCLINATION CASING INFORMATION 9.625" @ 9011' 7.625" @ 14320' EPOCH DEPTH SURVEY DATA 15088' PRESENT OPERATION= REAM TO BO'F]'OM WITH BIT #24 AZIMUTH VERTICAL DEPTH 12387.6 BIT INFORMATION NO. SIZE TYPE 23rrl 6.75 DPI CMM35F 24 6.75 HTC EP4983 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.5 VIS FC \1 SOL 90 10.86 INTERVAL S/N JETS IN OUT 1963902 15060 15088 G96JE 3X18 15088 HIGH LOW o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o o @ o DEPTH: 15078' PV 24 YP 12 SD OIL 74% CONDITION REASON FOOTAGE HOURS T/B/C PULLED 28 8.4 2/2-X-1 PR 0 AVERAGE CURRENT AVG 0 0 fi/hr 0 0 amps 0 0 Klbs 0 0 RPM 0 0 psi FL Gels 7/11/12 CL- 29000 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TOOLS TO GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL 15084 TO 15087' HIGH LOW AVERAGE 16 (TG) @ 15088 '4 (ClRC) @ 15088 5 TRIP GAS= 16 0 @ 0 0 @ 0 0 WIPER GAS= 0 CHROMATOGRAPHY(ppm) SURVEY= 0 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH= 0 0 @ 0 0 @ 0 0 AVG= 0 0 @ 0 0 @ 0 0 CURRENT 0 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 6 o @ o o @ o o 15084' TO 15087' GOOD OIL STAIN IN CORE, THE GAS WAS LOGGED AFTER THE TRIP (LAT). LITHOLOGY/REMARKS GAS DESCRIPTION CONGLOMERITIC SAND LAT CONGLOMERITIC SAND WITH GOOD OIL STAINS AND FAIR TO GOOD POROSITY. LITHOLOGY COAL, SILTSTONE, SANDSTONE, CONG SAND PRESENT LITHOLOGY 15088' COAL 100% DAILY ACTIVITY SUMMARY CORE #18 TO 15088', BACK REAM OUT OF THE HOLE FROM 15080' TO 15058', PULL OUT OF THE HOLE TO 14275', DROP DART, PUMP DRY JOB AND MONITOR THE WELL, PULL OUT OF THE HOLE AND LAY DOWN JARS, SURVEY TOOL AND CORE BARREL, SERVICE THE RIG, PICK UP BHA AND RUN IN THE HOLE WITH DRILL BITAND 3.5" DRILL PIPE TO 8150', BREAK CIRCULATION AND CHANGE OVER TO 5" HANDLING TOOLS, RUN INTO THE HOLE WITH 5" DRILL PIPE TO THE SHOE, CIRCULATE AND SHEAR DRILLING MUD, RUN IN THE HOLE TO 14489' "TIGHT", REAM FROM 14489' TO 144817', CONTINUE TO REAM... Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. FOREST Oil CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 17, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 15231 YESTERDAY 15088 24 Hour Footage 143 CASING INFORMATION 9,625" @ 9011' 7.625"@ 14320' DEPTH SURVEY DATA 15254 INCLINATION AZIMUTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS 24 6.75 HTC EP4983 G96JE 3X18 15088 21.75 EPOCH PRESENT OPERATION= SHORT TRIP VERTICAL DEPTH 12527' CONDITION REASON T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE RATE OF PENETRATION 65.0 @ 15145 1.0 @ 15088 10.1 SURFACE TORQUE 7140 @ 15229 3370 @ 15230 6407.9 WEIGHT ON BIT 27 @ 15100 7 @ 15088 20.9 ROTARY RPM 78 @ 15148 33 @ 15230 74.6 PUMP PRESSURE 3069 @ 15125 2261 @ 15196 2869.3 , ~ DRILLING MUD REPORT DEPTH: 15215' MW 9.6 VIS 78 PV 22 YP 9 FL Gels FC \1 SOL 10.95 SD OIL 71% MBL pH MWD SUMMARY INTERVAL TO TOOLS 5/10/12 CURRENT AVG 45.3 fi/hr 6178.9 amps 19.5 Klbs 62 RPM 2961 psi CL- Ca+ 28000 CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 22 @ 15145 5 @ 15191 8.5 CUTTING GAS 0 @ 0 0 @ 0 0 CHROMATOGRAPHY(ppm) METHANE(C-I) 3102 @ 15145 132 @ 15211 486.1 ETHAN E(C-2) 35 @ 15108 2 @ 15227 12.1 PROPANE(C-3) 14 @ 15104 1 @ 15204 5.2 BUTANE(C-4) 0 @ 0 0 @ 0 0.0 PENTANE(C-5) 0 @ 0 0 @ 0 0.0 TRiP GAS= 0 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 8 HYDROCARBON SHOWS INTERVAL NO SHOWS OF C-4 OR C-5 LAST 24 HRS LITHOLOGY/REMARKS LITHOLOGY SAND, SILT, COAL, CONGLOMERATE, CARBONACEOUS SHALE PRESENT LITHOLOGY 15230' = 80% COAL/CARB SHALE, 20% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY DRILL FORMATION FROM 15088' TO REPORT TIME. GAS DESCRIPTION Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F, BROWNE JR. FOREST OIL CORP REDOUBT UNIT #2 REPORT FOR DON JONES DATE May 18, 2001 TIME 04:00 DAILY WELLSITE REPORT DEPTH 15325 YESTERDAY 15231 24 Hour Footage 94 INCLINATION CASING INFORMATION 9.625 @ 9011' 7.625" @ 14320' , · , DEPTH SURVEY DATA 15325' EPOCH PRESENT OPERATION= TRIP OUT FOR E-LOGS AZIMUTH VERTICAL DEPTH 12587.4' BIT INFORMATION NO. SIZE TYPE SIN JETS 24 6.75 HTC EP4983 G96JE 3X18 INTERVAL IN OUT FOOTAGE 15088 15325 237 CONDITION REASON HOURS T/B/C PULLED 31.15 NA TD , , AVERAGE CURRENT AVG 12.0 7.6 ftJhr 6534.9 6424,9 amps 19.9 20.2 Klbs 73.9 72 RPM 2893.5 2606 psi DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU-I-I'ING GAS HIGH 45.3 @ 7474 @ 21 @ 83 @ 2963 @ LOW 15231 2.2 @ 15289 15310 3917 @ 15255 15289 11 @ 15241 15301 39 @ 15255 15257 2606 @ 15325 L DEPTH: VIS PV YP FL Gels CL- SOL SD OIL MBL pH Ca+ CCI , ,i HIGH METHANE(C-I) 2460 @ ETHANE(C-2) 24 @ PROPANE(C-3) 5 @ BUTANE(C-4) 0 PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL LITHOLOGY SILTSTONE, SAND, COAL, ASH PRESENT LITHOLOGY 15325' = 70% SILTSTONE, 30% SAND LOW AVERAGE 15310 3 @ 15234 8.5 TRIP GAS= 0 0 0 @ 0 0.0 WIPER GAS= 8 CHROMATOGRAPHY(ppm) SURVEY= 0 15310 132 @ 15268 542.1 CONNECTION GAS HIGH= 0 15300 1 @ 15319 4.0 AVG= 0 15231 1 @ 15324 0.3 CURRENT 0 0 0 @ 0 0 CURRENT BACKGROUND/AVG 0 o o @ o o , , , NO HYDROCARBON SHOWS THE LAST 24 HRS LITHOLOGY/REMARKS GAS DESCRIPTION ,,, , , DRILL FORMATION TO 15254', CIRCULATE DRILLING MUD AND MONITOR THE WELL, PULL UP TO THE SHOE FOR WIPER TRIP, HOLE IS TIGHT AT 14435' TO 14440', SERVICE THE RIG AND CHECK THE CROWN, RUN IN THE HOLE, TIGHT AT 14400' TO 14450', DRILL FORMATION FROM 15254' TO 15325', CIRCULATE AND CONDITION THE DRILLING MUD, MONIOTR THE WELL, WIPER TRIP TO THE SHOE, HOLE IS TIGHT AT 14427', RUN IN THE HOLE FROM 14320' TO 14416', HOLE IS TIGHT, REAM HOLE FROM 14410' TO 14460' TO WIPE OUT LEDGE, RUN TO THE BOTTOM OF THE HOLE WITHOUT ANY FILL, CIRCULATE DRILLING MUD AND CONDITION THE HOLE FOE E-LOGS, DROP DART AND BEGIN TO PULL OUT OF THE HOLE. DAILY ACTIVITY SUMMARY Epoch Personel On Board= 2 Daily Cost $1773 Report by: LEES F. BROWNE JR. Redoubt Unit # 2 APl: 50-733-20501-00 Forest Oil Corporation Production Test Results Enclosed are copies of all drill stem and production test data and charts for Redoubt Unit # 2. There were two drill stem tests run on RU # 2. The first test was in the lower Hemlock Zone from June 6 - June 11, 2001 at a depth of 14650'to 15183'MD. For both tests the bottom of the Mule shoe was placed at 14053' and the top of the plug was 15215'. The second test was run in the upper Hemlock Zone from June 14th- June 17th, 2001 at a measured depth of 14365' to ~ 14650'. The reservoir pressure was measured at 5325 psig ~ 12,000 TVD SS. The first, or lower Hemlock, test produced the following results: Drawdown Depths: 14,694',14755', 14860',14954', 14992', 15084', 15114', 15144' Oil Flow Rate: 247 bbl/d Water Rate: 0.4 bbl/d APl: 27.1 The second, or upper Hemlock, test produced the following results: Drawdown Depths: 14604', Oil Flow Rate: 733 bbl/d Water rate: 0.045 bbl/d API: 28.7 Production and rheology tests were performed by Oil Phase. These results are forthcoming. PRODUCTION TESTING SERVICES WELL . RU#2 D~,~E' . .... ~'3~¢G1.. /'"" t:~ '"1 c,~ ! ~.-!' .' "l:'c~:! T.,~,,:I~':,, 1..~.~.:1. ~" l':..~' ) :: il: '~"'l' c.o~. I i= i~.~tc.~:i~.~.l~..:o~ ]:.c..~ .l~..~~i,~:i-~- O~e.:l ;~;".'" .!. 'r'"'"'.'.l.C'~'~l ...s~ :1 r~' i..X.~,~ I ..~,'~ I. P.,i.~ .t' ~*,,¢ i '~i~.~ t. r~,,~. I s~ t'.c~r I '~w...to".~,".l'.'~.~.'l '~.."l:,~'.~':t~t~.:a.~'~.l. mm/~d/~l'hkmm't', hr .I .1' in.. i P~(~) l'" F !' '~,i(;>'linofh2et ..F .1' !n....I.'M~JCF/D.I ,~IaCF [.SCFre~LI::I~I :f ~1. 'l::'b'~_-._LL .W"'.l.'.::b~l '1.:'.:~.:.1'.': 5/30/01 13:00:00 0 Arrive on Osprey Platform begin rig up 0 0 0 0 0 0 5/31/01 611101 6/2/01 6/2/01 6/7/01 6/7101 6/7101 6/8/01 19:00:00 6 boat on location, begin spotting equipt. 23:30:00 10.5 discontinue dg up till AM 6:00:00 17 resume rig up 0:00:00 35 Continue rig up 3:00:00 62 Tubing parted rig down 12:00:00 71 Left Osprey platform 8:30:00 187.5 Arrive on Osprey 13:30:00 192.5 Off load boat begin rig up 23:00:00 202 Finish rig up and safety sytem test 0:08:00 203.1333 Packer set 3:00:00 206 Pressure tested separator line heater to 1000 psi held for 5 min 7:00:00 210 Pressure tested inlet manifold to 5 k held for 5 rain 7:00:00 210 Pressure tested safety valve to 5k held 5 minuets 7:15:00 210.25 Safety meeting wi all personnell 9:00:00 212 complete flare line p/t and separator blowdown 9:15:00 212.25 begin pumping N2 down tubing 11:15:00 214.25 N2 supply depleted, 1735 psi 11:25:00 214.4167 0 1735 11:30:00 214.5 open tester valve 11:31:00 214.5167 0 1750 11:45:00 214.75 0 1930 0 12:10:00 215.1667 open well thru adj. choke 10/64 12:15:00 215.25 1950 165 12:20:00 215.3333 1840 165 12:25:00 215.4167 adj. choke opened to 14 1755 12:30:00 215.5 1650 135 12:33:00 215.55 choke to 16/64 12:42:00 215.7 choke to 18/64 12:45:00 215.75 1285 12:48:00 215.8 choke to 48/64 12:52:00 215.8667 choke to 26~64 13:02:00 216.0333 choke to 32/64 13:15:00 216.25 100 13:30:00 216:5 tubing preSsure less than 50 psi 14:30:00 217.5 slight bubble 15:15:00 218.25 Slight bubble 15:30:00 218.5 Slight bubble 16:00:00 219 Slight bubble 16:43:00 219.7167 Fluids to surface 16:45:00 219.75 17:00:00 220 32 30 53 17:05:00 220.0833 Start injecting anti foam 17:30:00 220.5 32 50 18:00:00 221 32 30 54 18:00:00 221 APl gravity 25.4 18:30:00 221.5 32 15 57 19:00:00 222 32 30 57 i9:30:00 222.5 32 35 54 20:00:00 223 32 35 54 20:30:00 223.5 32 25 53 21:08:00 224 32 35 53 21:30:00 224.5 32 35 53 22:00:00 225 32 30 53 22:30:00 225.5 32 30 53 22:40:00 225.6667 Open choke to 64/64 0 0 0 0 0 2 74 1.5 0.262 0.005 1 70 0.186 0,006 2 76 0.206 0.008 2 100 0.203 0.014 0 0 0 0.4 0.4 33.9 o 0.4 6.3 5.9 141.6 6,3 0 0 8.5 2.2 52.8 8.5 0.018 0.018 0.432 17.5 9 216 17.5 0,024 0.006 0.134 21.6 4.1 98.4 21.6 0.024 0 0.01 47.7 26.1 626.4 47.7 0.024 0 0 0 0 0 0 33,882 0.4 25.4 0,018 0.8 52.8 8.5 24.6 0.024 0.1 216 17.5 25.6 0 0.024 0 98.4 21.6 27.3 0 0.024 0 626.4 47.7 26.2 0 0 0 0 141.6 6.3 0.5 6/9/01 6/10/01 6/10/01 6/13/01 6/14/01 22:45:00 23:00:00 23:30:00 0:00:00 0:30:00 1:00:00 1:30:00 2:00:00 2:30:00 3:00:00 3:30:00 4:00:00 4:30:00 5:00:00 5:30:00 6:00:00 6:30:00 7:00:00 7:12:00 7:30:00 7:50:00 8:00:00 2:55:00 2:56:00 3:00:00 3:05:00 3:08:00 4:00:00 5:00:00 5:02:00 5:30:00 5:35:00 5:45:00 6:00:00 6:30:00 6:45:00 7:00:00 7:05:00 8:00:00 9:00:00 10:00:00 11:00:00 12:00:00 12:30:00 14:21:00 14:55:00 15:00:00 16:35:00 16:40:00 16:40:00 20:30:00 23:45:00 0:30:00 1:25:00 1:45:00 2:00:00 4:18:00 5:03:00 5:07:00 5:08:00 5:09:00 5:10:00 225.75 226 226.5 227 227.5 228 228.5 229 229.5 230 230.5 231 231.5 232 232.5 233 233.5 234 234.2 234.5 234.8333 235 253.9167 253.9333 254 254.0833 254,1333 255 256 256.0333 256.5 256.5833 256.75 257 257.5 257.75 258 258.0833 259 260 261 262 263 263.5 265.35 265.9167 266 267.5833 267.6667 267.6667 343.5 346.75 347.5 348.4167 348.75 349 351.3 352.05 352,1167 352.1333 352.15 352.1667 CONFIDENTIAL Bypass inlet choke 128 10 64 128 5 51 128 15 52 128 15 52 128 10 54 128 10 54 128 10 55 128 10 55 128 5 54 128 3 54 128 25 55 128 15 55 128 25 57 128 10 56 128 10 55 128 10 55 128 10 55 Shut in downhole valve. No more flow at surface. Shut in ESD valve for pressure build up. 0 Bleed down pressure above downhole valve Choke full open Downhole valve open zero bubble slight bubble slight bubble, no fluid to surface bubble, no fluid fluid to surface no fluid to surface fluid to surface Wireline RIH 8 56 12 56 20 56 25 56 14 56 0 no fluid to surface 0 Wireline GIH 0 Close D/H omni valve 0 Wireline POOH 0 57 59 59 down wireline 64 59 Wireline OOH, SlW @ manifold,rig Start well kill open well 100 Fluid to surface 46 Pumping fluids down annulus, unable to measure Shut in well, rig down manifold and flowline, prepare to pull pipe. 209.64 bbls flowed to tanks during kill Total tank bbls including flush 467.5 Begin rig up rig up complete, begin p/t p/t sep inlet to 1000 psi, all lines good p/t choke manifold to 4000 psi safety meeting with all involved personnell begin pumping N2 to 1900 psi N2 pumping complete Bar dropped, guns fired 1915 1935 1950 1970 60.7 80.5 97.2 114.1 133.9 145.5 169.9 183.5 192.2 203,1 203.1 211.36 229,73 232.2 242.52 256.56 269.36 13 19.8 16.7 16.9 19.8 11.6 24.4 13.6 8.7 10.9 8.26 18.37 2.47 10.32 14.04 12.8 312 475.2 400.8 405.6 475.2 278.4 585.6 326.4 208.8 261.6 205,1 440,9 59,3 123,8 337 307.2 60.7 80.5 97.2 114.1 133.9 145.5 169.9 183.5 192.2 203.1 203.1 211.4 229,7 232.2 242.5 256.6 269.4 0.024 0.024 0.024 0.193 0.193 0.193 0.193 0.193 0.28 0.497 0.497 0.513 0.549 0.549 0.561 0.575 0.575 0 0 0 0.169 0 0 0 0 0.087 0,217 0 o o 4.056 o o o o 2.088 5.208 0.016 0,036 0 0.012 0.014 0 0.024 0.024 0.024 0.193 0.193 0.193 0.193 0.193 0.28 0.497 0 312 0 475.2 0 400.8 1 405.6 0 475.2 0 278.4 0 585.6 0 326,4 1 208.8 2 261,6 0 0 0.497 0 0 0.397 0.513 0.549 0.549 0.561 0.575 0.575 0.864 0 0.144 0.336 0 0.2 205.076 0.2 440.88 0 59.28 0.1 123.84 0.1 336.96 0 307.2 60.7 27.1 80.5 27.7 97.2 27.7 114.1 27.3 133.9 27.8 145.5 27.3 169.9 27.4 183.5 27.3 192.2 27.3 203,1 27.2 203.1 211.36 26.2 229,73 26,1 232.2 242.52 256.56 269,36 5:11:00 5:13:00 5:15:00 5:17:00 5:19:00 5:21:00 5:23:00 5:25:00 5:27:00 5:29:00 5:31:00 5:33:00 5:35:00 5:35:00 5:37:00 5:40:00 5:50:00 5:58:00 6:00:00 6:30:00 6:50:00 7:00:00 7:10:00 7:30:00 8:00:00 8:15:00 8:30:00 9:00:00 9:15:00 9:30:00 9:45:00 10:00:00 10:30:00 10:45:00 11:00:00 11:15:00 11:30:00 11:45:00 12:00:00 12:03:00 12:15:00 12:30:00 12:45:00 13:00:00 13:15:00 13:30:00 13:45:00 14:00:00 14:15:00 14:30:00 14:45:00 15:00:00 15:15:00 15:30:00 15:45:00 16:00:00 16:15:00 16:30:00 16:45:00 17:00:00 17:30:00 17: 45:00 352.1833 352.2167 352.25 352.2833 352.3167 352.35 352.3833 352.4167 352.45 352.4833 352.5167 352.55 352.5833 352.5833 352.6167 352.6667 352.8333 352.9667 353 353.5 353.8333 354 354.1667 354.5 355 355.25 355.5 356 356.25 356.5 356.75 357 357.5 357.75 358 358.25 358.5 358.75 359 359.O5 359.25 359.5 359.75 360 360.25 360.5 360~75 361 361.25 361.5 361.75 362 362.25 362.5 362.75 363 363.25 363.5 363.75 364 364.5 364.75 2000 2050 2080 2120 2150 2180 2210 2235 2260 2285 2305 2325 2343 open well to sep. choke at 16/64 16 2362 16 2250 open choke to 20~64 plate in service 315 20 1390 56 20 545 54 open choke to 24/64 24 120 55 set choke on line heater to 32/64, open bypass on inlet manifold no fluid to surface, slight bubble No fluid, slight bubble. Fluid to surface. 32 40 32 30 inlet sample 2.0% w/c inlet sample 25.0% w/c inlet sample 15.0% w/c 32 35 inlet sample 6.0% inlet sample 3.5 % 32' 50 inlet sample 1.1% w/c inlet sample 0,5% w/c inlet sample 0.75% w/c 32 25 56 2" choke full open inlet sample, trace H20 inlet sample, trace H20 inlet sample, trace H20 128 20 56 inlet sample 0.20% w/c inlet sample 0.20% w/c inlet sample 0.20% w/c 128 17 56 inlet sample 0.1% inlet sample 0.1% inlet sample, trace H20 128 19 56 inlet sample 0.1 inlet sample 0.1 inlet sample, trace H20 19 56 inlet sample 0.1% w/c inlet sample, trace H20 inlet sample, trace H20 18 57 inlet sample, trace H20 inlet sample, trace H20 2.125 1.935 6.101 o 33.9 62.59 95.61 131,11 162.91 195.95 230.64 264.51 296.31 -269.36 33.9 28,69 33.02 35,5 31.8' 33.04 34.69 33.87 31.8 0 lO84.8 688.6 792.5 852 763.2 793 832.6 812.9 763.2 269.4 303.3 331.9 365 400.5 432.3 465.3 5OO 533.9 565.7 0 0.396 4.116 5,856 6.07 6.12 6.18 6.21 6.24 6.27 -0.575 0.396 3.72 1.74 0,214 0,(35 0.06 0.03 0.03 0.03 o 12.672 89.28 41.76 5.136 1.2 1.44 0.72 0.72 0.72 0.575 0.971 .4.691 6.431 6.645 6.695 6.755 6.785 6.815 6.845 o 1.2 11.5 0.6 0.2 0.2 0.1 0.1 0.1 o 1084.8 688.56 792.48 852 763.2 792.96 832.56 812.88 763.2 269.36 303.26 26.55 331.95 25.45 364.97 26.6 400.47 26.45 432.27 26.9 465.31 26.5 500 27 533.87 27.2 565.67 27.3 25000 6/15/01 6/16t01 18:00:00 18:15:00 18:30;00 18:45:00 19:00:00 19:00:00 19:10:00 19:22:00 19:23:00 9:00:00 9:02:00 9:05:00 9:15:00 9:30:00 9:33:00 9:45:00 10:00:00 10:00:00 10:15:00 10;30:00 10:45:00 11:00:00 11:00:00 11:15:00 11:30:00 11:45:00 12:00:00 12:00:00 12:15:00 12:30:00 12:45:00 13: 00:00 13:00:00 13:15:00 13:30:00 13:30:00 17:30:00 17:38:00 18:00:00 18:05:00 18:22:00 19:00:00 19:00:00 20:00:00 20:00:00 21:00;00 21:00:00 22:00:00 22:00:00 23:00:00 23:00:00 0:00:00 0:00:00 1:00:00 1:00:00 2:00:00 2:00:00 3:00:00 3:00:00 4:00:00 4:00:00 5:00:00 365 365.25 365.5 365.75 366 366 366.1667 366.3667 366.3833 380 380,0333 380.0833 380.25 380.5 380.55 380.75 381 381 381.25 381.5 381.75 382 382 382.25 382.5 382,75 383 383 383.25 383,5 383,75 384.00 384.00 384.25 384.50 384.50 388,50 388,63 389.00 389,08 389.37 390.00 390.00 391.00 391.00 392,00 392.00 393,00 393.00 394.00 394.00 395.00 395,0O 396.00 396,0O 397.0O 397.00 398.00 398,00 399.00 399,00 400.00 15 57 inlet sample, trace H20 inlet sample, trace H20 inlet sample, trace H20 16 57 downhole valve closed 0 psi at surface, monitor for 30 minutes shut in at inlet manifold shut in at ESD valve Surface shut in pressure 140 psi Cycle Haliburton valve open 140 slight bubble in bucket Slight bubble 5 57 Fluids to surface Inlet sample 0% h2o Inlet sample 0% h2o 38 58 APl 30 @ 80 F Inlet sample 0% h2o inlet sample 0% h20 21 57 Inlet sample 10% h2o Inlet sample 0% h2o APl 29 @ 83 F Inlet sample 0% h2o Inlet sample 0% h2o Inlet sample 0% h2o Inlet sample 0% h2o APl 29.5 @ 83 Inlet sample .3% h2o Inlet sample 0% h2o Inlet sample 0% h2o Inlet sample 0% h2o 16 57 APl 29.25 @ 78 F Inlet. sample 0% h2o Inlet sample 0% h2o 15 57 APl 29.25 @ 74 F, Shut in Halliburton valve E-line OOH, rigged down LPRN valve cycled open 0 20 SITP 38 psig. Open choke to 128/64 adj. choke. Fluid to surface. 128 38 57 APl 29.6 @ 60 F 128 2O 57 APl 29 @ 73 F 128 19 57 APl 29.2 @ 73 F 128 19 57 APl 29 @ 72 F 128 25 56 APl 29.1 @ 74 F 128 17 56 APl 29.2 ¢__, 72 128 15 56 APl 29.6 @ 80 F 128 17 56 APl 29.2 ~ 75 F 128 18 55 APl 29.4 @ 77 F 128 20 56 APl 29.6 @ 78 F 128 20 56 328.52 361.56 365.06 365.06 413.26 425.29 458.82 489.49 506.79 529.48 55877 590.16 623.61 655.41 687.21 720.25 752.85 783.4 816.83 847.78 32.21 33.04 3.5 0 48.2 12.03 33.53 30.67 17.3 22.69 29.29 31.39 33,45 31.8 31.8 33.04 32.6 30.55 33.43 30.95 773 793 229.1 0 1217.7 577.4 804.7 736.1 830.4 99 703 753.4 802.8 763,2 763,2 793 782.4 733.2 802.3 742.8 597.9 630.9 634.4 634,4 682.6 694.6 728.2 758.8 776.1 798.8 828.1 859.5 893 924~8 956.6 989,6 1022.2 1052.8 1086.2 1117.1 6.3 63 6.3 6.3 7.475 7,475 7,475 7,705 7,705 7.705 7.705 7.7O5 7.705 7.705 7.7O5 7.7O5 7.705 7,705 7.705 7.705 0.03 0 0 0 1,175 0 0 0.23 0 0.72 0 0 0 29.684 0 0 5,52 0 6.875 6.875 6.875 6,875 8.05 8.05 8.05 8.28 8.28 8.28 8.28 8.28 8.28 8.28 8.28 8.28 8.28 8.28 8.28 8.28 0.1 773.04 597.88 27 0 792.96 630,92 27.1 0 229,091 634.42 0 0 634.42 28.6 28.6 2.4 1217.684 682.62 0 577.44 694.65 27.4 0 804.72 728.18 27.9 0,7 736.08 758.85 28 0 830.4 776.15 28.3 0 99.011 798.84 28.9 0 702.96 828.13 28,1 0 753,36 859.52 28,3 0 802.8 892.97 28.2 0 763.2 924.77 28.1 0 763.2 956.57 28.4 0 792.96 989.61 28.2 0 782.4 1022.21 28.2 0 733.2 1052,76 28.2 0 802.32 1086.19 28.3 0 742.8 1117.14 28.3 CONFIDENTIAL 5:00:00 400.00 APl 29.8 @ 81F 6:00:00 401.00 15 57 6:00:00 401.00 APl 29.6 @ 88 F 7:00:00 402.00 20 57 7:00:00 402.00 APl 29.8 @ 92 F 8:00:00 403.00 128 15 57 8:00:00 403.00 APl 30.0 @ 88 F 9:00:00 404,00 128 15 57 9:00:00 404.00 APl 30.0 @ 88 F 9:07:00 404.12 SWACO injecting C-tank 10:00:00 405.00 128 15 58 10:00:00 405.00 APl 30.2 @ 98 F 10:30:00 405.50 10:30:00 405.50 SWACO injected C-tank 10:38:00 405.63 SWACO injecting B-tank 11:00:00 406.00 128 17 62 11:00:00 406.00 APl 30.1 @98F 12:00:00 407.00 128 16 66 12:00:00 407.00 APl Gravity 30.3 @ 99 F 13:00:00 408.00 SWACO injected B-tank 13:00:00 408.00 128 13 65 13:00:00 408.00 APl 30.0 @ 92 F 14:00:00 409.00 128 11 57 14:00:00 409.00 APl 29.8 @ 84 F 15:00:00 410.00 128 13 54 15:00:00 410.00 APl 29.8 @79 F 16:00:00 411.00 128 12 54 16:00:00 411.00 APl 29.5 @73 F 17:00:00 412.00 128 10 54 17:00:00 412.00 APl 29.@ 76 F 18:00:00 413.00 128 15 54 18:00:00 413.00 APl 29.6@81 F 19:00:00 414.00 128 17 55 19:00:00 414.00 APl 29.6 @81 F 20:00:00 415.00 128 16 55 20:00:00 415.00 APl 29.4@ 78 F 21:00:00 416.00 128 14 55 21:00:00 416.00 APl 29.2 @ 76 F 22:00:00 417.00 128 19 54 22:00:00 417,00 APl 29.6 @ 81 F 23:00:00 418.00 128 17 54 23:00:00 418.00 29.8 APl @ 84 F 6/17/01 0:00:00 419.00 128 17 54 0:00:00 419.00 APl 29.6 @ 82 F 1:00:00 420.00 128 22 54 1:00:00 420.00 APl 29.6@81 F 2:00:00 421.00 128 20 54 2:00:00 421.00 APl 29.8 @ 84 F 3:00:00 422.00 128 21 54 3:00:00 422.00 APl 29.6 @ 81 4:00:00 423.00 128 20 54 4:00:00 423.00 APl 29.6 @ 79 F 5:00:00 424.00 128 21 54 5:00:00 424.00 APl 29.6 @ 81 F , 6:00:00 425.00 128 20 54 6:00:00 425.00 APl 29.8 @ 88 F 6:30:00 425.50 SWACO injecting B-tank 8:00:00 427.00 128 . 10 56 8:00:00 427.00 APl 29.8 @ 88 F 8:15:00 427.25 SWACO injected B-tank 8:30:00 427.50 128 18 62 8:30:00 427.50 APl 30.0 @ 92 F 877.37 29.59 710.2 1146.7 7.705 912.46 35.09 842.2 1181.8 7.705 944.35 31.89 765.4 1213.7 7.705 973.55 29.2 700.8 1242.9 7.705 1020.62 47.07 753.1 1290 7.705 1097.39 76.77 737 1366.8 7.705 1127.04 29.65 711.6 1396.4 7.705 1156.23 29.19 700.6 1425.6 7.705 1187.13 30.9 741.6 1456.5 7.705 1217.39 30.26 726.2 1486.8 7.705 1248.48 31.09 746.2 1517.8 7.705 1279.03 30.55 733.2 1548.4 7.705 1307.1 28.07 673.7 1576.5 7.705 1337.47 30.37 728.9 1606.8 7.705 1368.84 31.37 752.9 1638.2 7.705 1401.21 32.37 776.9 1670.6 7.705 1429.25 28.04 673 1698.6 7.705 1457,32 28.07 673.7 1726.7 7.705 1487.07 29.75 714 1756.4 7.705 1518.44 31.37 752.9 1787.8 7.705 1547.33 28.89 693.4 1816.7 7.705 1575.4 28.07 673.7 1844.8 7.705 1605.94 30.54 733 1875.3 7.705 1678,95 73.01 700.9 1948,3 7.705 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8,28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8,28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 8.28 0 710,16 1146.73 27.7 0 842.16 1181.82 27.6 0 765.36 1213.71 28 0 700.8 1242.91 28 27.5 0 753.12 1289.98 27.9 27.5 0 736.992 1366.75 27.8 0 711.6 1396.4 28.1 0 700.56 1425.59 28.5 0 741.6 1456.49 28.5 0 726.24 1486.75 28.1 0 746.16 1517.84 28.1 0 733.2 1548.39 28.1 0 673.68 1576,46 28.2 0 728.88 1606.83 28.1 0 752.88 1638.2 28.1 0 776.88 1670.57 28.1 0 672.96 1698.61 28.1 0 673.68 1726.68 28.1 0 714 1756.43 28.2 0 752.88 1787.8 28.1 0 693.36 1816.69 28.3 0 673,66 1844.76 28.1 0 732.96 1875.3 27.8 27.9 0 700.896 1948.31 27.8 8:40:00 427.67 SWACO injecting C-tank 9:00:00 428.00 128 18 9:00:00 428.00 APl 29.8 @ 85 F 10:00:00 429.00 128 15 10:00:00 429.00 APl 29.8 @ 85 F 10:30:00 429.50 128 10 10:30:00 429.50 APl 29.7 @ 74 F 10:42:00 429.70 Halliburton cycling tools 11:18:00 430.30 Start reverse out 12:33:00 431.55 End reverse out 187 bbls flowed to C-tank 1740.03 61.08 733 2009.4 7.705 7.705 7.75 0 0 0.045 0 0 2.16 8.28 8.28 8.325 0.3 732.96 2009.39 28.1 28.1 28.7 4,000 3,500 3,000 2,500 2,000 1,500 1,000 5OO Redoubt Shoal Inflow Performance Data 0 5OO Reservoir Pressure: 5325 psig @ 12,000' TVD SS ·-..:'." ~:.'.:'"'i .i:.'' ..:.:...:....:':~ 1000 1500 2000 2500 3000 '"" -· :.. I :':": ' · .... :: :~:~:~:: :::'~ · · : ' ¢ 1 ~RU#2 Flow to Tanks (Total Hemlock) ...':i;--'-RU#2 Flow to Tanks (U. HK only) RU#2 Flow to Tanks (L. HK only) 3500 4000 45O0 50OO Bottomhole Flowing Pressure (psig) 55OO KWG:RU21PR.xIs(RU2_U.HK_IPR) 7/5/01 Measumd Depth 14424.01 14443.92 14473.99 14533.97 14564.04 14604.03 14634 14663.92 14693.88 14723.91 14754.91 14783.98 14813.95 14860.05 14883.97 14924.06 14953.96 14992.03 15025,98 15053.89 15083.94 15114,03 15144.02 Plot Data: 14875 14875 14650 14650 14365 14365 15183 15183 TVDKB 11,834.67 11,850.88 11,875.57 11,924.94 11,949.78 11,982.99 12,007.92 12,033.03 12,058.17 12,083.41 12,109.59 12,134.14 12,159.49 12,198.66 12,218.99 12,253.30 12,279.02 12,311.76 12,341.10 12,365.34 12,391.72 12,418.14 12,444.46 12,211.37 12,211.37 12,021.35 12,021.35 11,786.92 11,786.92 12,479.24 12,479.24 TVDSS 11,774.98 11,791.19 11,815.88 11,865.25 11,890.09 11,923.30 11,948.23 11,973.34 11,998.48 12,023.72 12,049.90 12,074.45 12,099.80 12,138.97 12,159.30 12,193.61 12,219.33 12,252.07 12,281.41 12,305.65 12,332.03 12,358.45 12,384.77 12,151.68 12,151.68 11,961.66 11,961.66 11,727.23 11,727.23 12,419.55 12,419.55 RU#2 RFT Data DD Mobility (md/cp) DD Permeability (md) Formation Pressure 1.32 0.60 5253.95 10.29 4.70 5282.12 0.41 0.19 5296 0.6 0.27 5325.74 1.54 0.70 5336.99 0.55 0.25 5347.45 6.8 3.11 5356.05 0.17 0.08 5376.61 0.16 0.07 5441.47 0.04 0.02 5453.29 0.87 0.40 5479.18 0.15 0.07 5489.99 0.09 0.04 5523.32 0.05 0.02 5518.61 Test Type Unrecognizable Unrecognizable Dry Test Normal Pretest Normal Pretest Limited Drawdown Lost Seal Dry Test Limited Drawdown Normal Pretest Limited Drawdown Normal Pretest Dry Test Limited Drawdown Dry Test Dry Test Limited Drawdown Limited Drawdown Dry Test Normal Pretest Limited Drawdown Limited Drawdown Limited Drawdown 0 5550 0 5550 0 5550 0 5550 Division between Upper and Lower Hemlock Depositional Units Division between Upper and Lower Hemlock Depositional Units Division between Upper and Lower Hemlock Well Tests Division between Upper and Lower Hemlock Well Tests Top Hemlock Top Hemlock Bottom Hemlock Bottom Hemlock Redoubt Unit #2 RFT Data 11,700 11 11,850 11,900 11,950 .-. 12,000 ~ 12,050 > ~ ~ 12,100 ~ 12,150 12,200 12,250 12,300 12,350 12,400 12,450 . 5250 I I:' Top Hemlock '~;:!':';?'~~w~"l""='" ='"' "="'=":'"::'.'.! .i """;'" '':f '" ~= ..... 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"'"":" ;":'-}';:-;':;.r.""'.:-'""?',;'?;::;'.:.":.'";".'".:';". ".7...,..: ~".,-':";:.'....,.'i" "' '""' :..'"v?;'..'".:."' ,' :"'..':;:..:'... ",~ ":';,;': :.'. :..7.. '::..-.:';....~..;';. '"."'.' '::'";,.:-'"'"';'""" '..:'"/-{;;;':' "i"..;";'i..:'.: ',,: ...... "-:' '". '. i':' .'..:!7 ./'..~._.'-_..;-i%~._..: % ". '.' %'?:f':;...;/.:-'.!::'! :.~':';' ::-,'? ,.~:;.::.'- .":./..:.'"."-:'.-;."~: ":":,'::'%:-..:;'.;. ;:..; I:..'" ~ '".?:._';.* :2. '":...i .,;;/"~.}:' '..'"i~.'" .. '..:.? ·, ~9'; ·:~·., ~~ '· ~ i ·. '::_;. __-~- =---~-. · '"'" -:' "::'" "'"-'":;'. ........ "~';'"'" "" '"' '"" ':"":'"'" I .... ' '- " " ..... ' :'". ":";'" '""':':" ':':'/''::":,'."'..*'. "'~'* : .... """ ' "~ .... '*'~ "':' · ': .' :': Base Hemlock: ........ ~...., -~.....:....:- : .:~,...: .., .. ........ ...:.......:..: ..... ...- . ...~ :- . ............ ................ .., .......... · ......... , ?, .: ......... :...:. ~ · ';!:.:'?. ":...'~ ": '.'-' .... '- ' [. :~.:':.' ;'!':.... :-;.'??.'"::. 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C·.; :.:~:.'?/ ? :: :}: ?: :~' !?~!~.--'.: } 2., i. ~·' ~ 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 Formation Pressure (psig) CONFi%NTIAL RU#2 Directional Data Measured Depth 14 233.56 14 372.60 14 438.24 14 458.64 14,515.76 14559.20 14 630.12 14718.12 14 8O6.O0 14 900.00 15 004.00 15 049.00 15 144.12 15 238.12 15 325.00 TVDKB 11 682.73 11 792.94 11 846.22 11 862.95 11 909.92 11 945.76 12,004.66 12,078.52 12 152.73 12 232.61 12 322.05 12 361.05 12 444.55 12 528.43 12 606.52 TVDSS 11 11 11 11 11 11 11 12 12 12 12 12 12 12 12 623.04 733.25 786.53 803.26 850.23 886.07 944.97 018.83 093.04 172.92 262.36 301.36 ,384.86 468.74 546.83 14875 1465O 14365 15183 12211.36532 12O21.34565 11786.91586 12479.2442 12,151.68 11,961.66 11,727.23 12,419.55 PRODUCTION TESTING SERVICES WELL 6/15/01 6/16/01 6/17/01 RU#2 DATE 5'3C,'01 Clock Cum ,I ] Choke Time Time I Comments Size hh:mm hr J in 6:14.'01 5'03 352 05 Bar dropped, guns flrod 6/14/01 8:15 355.25 Fluid to surface. 6/14/01 9:00 356 32 6/14/01 10:00 357 32 6/14/01 11:00 358 32 6/14/01 12:00 359 32 6/14/01 13:00 360 128 6/14/01 14:00 361 128 6/14/01 15:00 362 128 6/14/01 16:00 363 6/14/01 17:00 364 6/14/01 18:00 365 6/14/01 19:00 366 6/14/01 19:22 366.3667 shut in at inlet manifold 6/14/01 19:23 366.3833 shut in at ESD valve 6/16/01 9:02 380.0333 Cycle Haliburton valve open 6/15/01 9:33 380.55 Fluids to surface 6/15/01 10:30 381.5 inlet sample 0% h20 6/15/01 11:00 382 Inlet sample 0% h2o 6/15/01 12:00 383 Inlet sample 0% h2o 6/15/01 13:00 384.00 Inlet sample 0% h2o 6/15/01 13:30 384.50 Inlet sample 0% h2o 6/15/01 13:30 384.50 Shut in Halliburton valve 6/15/01 17:38 388.63 LPRN valve cycled open 6/15/01 18:22 389.37 Fluid to surface. 6/15/01 19:00 390.00 128 6/15/01 20:00 391.00 128 6/15/01 21:00 392.00 128 6/15/01 22:00 393.00 128 6/15/01 23:00 394.00 128 6/16/01 0:00 395.00 128 6/16/01 1:00 396.00 128 6/16/01 2:00 397.00 128 6/16/01 3:00 398.00 128 6/16/01 4:00 399.00 128 6/16/01 5:00 400.00 128 6/16/01 6:00 401.00 6/16/01 7:00 402.00 6/16/01 8:00 403.00 128 6/16/01 9:00 404.00 128 6/16/01 10:00 405.00 128 6/16/01 10:30 405.50 6/16/01 11:00 406.00 128 6/16/01 12:00 407.00 128 6/16/01 13:00 408.00 128 6/16/01 14:00 409.00 128 6/16/01 15:00 410.00 128 6/16/01 16:00 411.00 128 6/16/01 17:00 412.00 128 6/1 6/01 18:00 413.00 128 6/16/01 19:00 414.00 128 6/16/01 20:00 415.00 128 6/16/01 21:00 416.00 128 6/16/01 22:00 417.00 128 6/16/01 23:00 418.00 128 6/17/01 0:00 419.00 128 6/17/01 1:00 420.00 128 6/17/01 2:00 421.00 128 6/17/01 3:00 422.00 128 6/17/01 4:00 423.00 128 6/17/01 5:00 424.00 128 6/17/01 6:00 425.00 128 [Tubing 1Tubing ~ncre'me. ntat Oil I °"~: 1 I ,=res I Temp I Tim I ..'.re ! Fluid i,=,P l psi.;¢ I F / (bourn) t (,BOPD) I bU / AF'II 0.0 0.0 269.36 30 0.8 1084.8 303.26 26.55 35 1.7 688.6 331.95 25.45 50 2.8 792.5 364.97 26.6 25 56 3.8 852.0 400.47 26.45 20 56 4.7 763.2 432.27 26.9 17 56 5.8 793.0 465.31 26.5 19 56 6.8 832.6 500 27 19 56 7.7 812.9 533.87 27.2 18 57 8.8 763.2 565.67 27.3 15 57 9.8 773.0 597.88 27 16 57 10.7 793.0 630.92 27.1 11.1 229.1 634.42 11.1 24.8 25.3 0.0 634.42 28.6 21 57 26.3 1217.7 682.62 26.8 577.4 694.65 27.4 27.8 804.7 728.18 27.9 16 57 28.7 736.1 758.85 28 15 57 29.3 830.4 776.15 28.3 29.3 33.4 34.1 38 57 34.7 99.0 798.84 28.9 20 57 35.8 703.0 828.13 28.1 19 57 36.8 753.4 859.52 28.3 19 57 37.7 802.8 892.97 28.2 25 56 38.8 763.2 924.77 28.1 17 56 39.8 763.2 956.57 28.4 15 56 40.7 793.0 989.61 28.2 17 56 41.8 782.4 1022.21 28.2 18 55 42.8 733.2 1052.76 28.2 20 56 43.7 802.3 1086.19 28.3 20 56 44.8 742.8 1117.14 28.3 15 57 45.8 710.2 1146.73 27.7 20 57 46.7 842.2 1181.82 27.6 15 57 47.8 765.4 1213.71 28 15 57 48.8 700.8 1242.91 28 15 58 49.7 27.5 50.3 753.1 1289.98 17 62 50.8 27.9 16 66 51.8 27.5 13 65 52.7 737.0 1366.75 27.8 11 57 53.8 711.6 1396.4 28.1 13 54 54.8 700.6 1425.59 28.5 12 54 55.7 741.6 1456.49 28.5 10 54 56.8 726.2 1486.75 28.1 15 54 57.8 746.2 1517.84 28.1 17 55 58.7 733.2 1548.39 28.1 16 55 59.8 673.7 1576.46 28.2 14 55 60.8 728.9 1606.83 28.1 19 54 61.7 752.9 1638.2 28.1 17 54 62.8 776.9 1670.57 28.1 17 54 63.8 673.0 1698.61 28.1 22 54 64.7 673.7 1726.68 28.1 20 54 65.8 714.0 1756.43 28.2 21 54 66.8 752.9 1787.8 28.1 20 54 67.7 693.4 1816.69 28.3 21 54 68.8 673.7 1844.76 28.1 20 54 69.8 733.0 1875.3 27.8 6/17/01 8:00 427.00 6/17/01 8:30 427.50 6/17/01 9:00 428.00 6/17/01 10:00 429.00 6/17/01 10:30 429.50 128 128 128 128 128 10 56 71.8 27.9 18 62 72.2 700.9 1948.31 27.8 18 62 72.8 28.1 15 66 73.7 28.1 10 66 74.3 733.0 2009.39 28.7 RU#2 Upper Hemlock Welltest Rates 1000.0 975.0 950.0 925.0 900.0 875.0 850.0 825.0 800.0 775.0 750.0 725.0 70O.O 675.0 650.0 625.0 600.0 575.0 550.0 525.0 500.0 , 0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 Hours Redoubt Unit # 2 Lower Hemlock Drill Stem Test Summary of Flow Periods Start Time End Time Flow Period Elapsed Time Total Production 6/7/01 11:35 6/7/01 12:15 Surface Shut In 0.67 hrs 26 bbls 6/7/01 12:15 6/7/01 16:43 Fluid to Surface 4.47 hrs 131 bbls 6/7/01 16:43 6/7/01 18:00 Flow to Separator 1.28 hfs 6 bbls 6/7/01 18:00 6/7/01 19:00 Flow to Separator 1.00 hrs 2 bbls 6/7/01 19:00 6/7/01 20:00 Flow to Separator 1.00 hrs 9 bbls 6/7/01 20:00 6/7/01 21:00 Flow to Separator 1.00 hrs 4 bbls 6/7/01 21:00 6/7/01 22:00 Flow to Separator 1.00 hrs 26 bbls 6/7/01 22:00 6/7/01 23:00 Flow to Separator 1.00 hrs 13 bbls 6/7/01 23:00 6/8/01 0:00 Flow to Separator 1.00 hrs 20 bbls 6/8/01 0:00 6/8/01 1:00 Flow to Separator 1.00 hrs 17 bbls 6/8/01 1:00 6/8/01 2:00 Flow to Separator 1.00 hrs 17 bbls 6/8/01 2:00 6/8/01 3:00 Flow to Separator 1.00 hrs 20 bbls 6/8/01 3:00 6/8/01 4:00 Flow to Separator 1.00 hrs 12 bbls 6/8/01 4:00 6/8/01 5:00 Flow to Separator 1.00 hfs 24 bbls 6/8/01 5:00 6/8/01 6:00 Flow to Separator 1.00 hfs 14 bbls 6/8/01 6:00 6/8/01 7:00 Flow to Separator 1.00 hfs 9 bbls 6/8/01 7:00 6/8/01 7:50 Flow after BH Shutin 0.83 hrs 11 bbls Fluid Rate 936 BPD 704 BPD 117 BPD 43 BPD 216 BPD 98 BPD 626 BPD 312 BPD 475 BPD 401 BPD 402 BPD 475 BPD 278 BPD 586 BPD 326 BPD 207 BPD 314 BPD 6/7/01 16:43 6/8/01 7:00 Total Flow to Separator 14.28 hrs 202 bbls 6/7/01 11:35 6/8/01 7:00 Total Flow 19.42 hrs 359 bbls 340 BPD 444 BPD KWG:RU21PR.xls(L.HK DST ProdSumm) 7/5/01 Redoubt Unit #2 Lower Hemlock Drill String Test Completion Data Depth (WLM) Depth(TVDKB) ID UnitVolume Volume Item (ft) (ft) (in) (bbls/ft) (bbls) Test Tree 0 0 Top 5" Drill Pipe 0 0 4.214 0.0173 Btm 5"Drill Pipe 6,036 5,143 4.214 0.0173 104 Top 3.5" Drill Pipe 6,036 5,143 2.602 0.0066 0 LPRN Valve 14,012 11,502 2.602 0.0066 52 Middle 7-5/8" Packer 14,048 11,532 2.602 0.0066 0 Btm of Mule Shoe 14,053 11,536 2.602 0.0066 0 Total Vol. (bbls) 157 157 Btm of 7-5/8" Packer Top of 5-1/2" Liner Top Perforation Midpoint Perforations Bottom Hemlock Bottom Perforation Top of Plug 14,052 11,535 4.892 0.0232 14,112 11,583 4.892 0.0232 1 14,682 12,043 4.892 0.0232 13 14,941 12,263 4.892 0.0232 6 15,156 12,450 4.892 0.0232 5 15,200 12,489 4.892 0.0232 1 15,218 12,505 4.892 0.0232 0 15 21 27 Average wellbore angle through lower Hemlock perforations: 30.1 degrees, cos = .865 KWG:RU21PR.xIs(RU2_L. H K_DST_ComplData) 7/5/01 PRODUCTION TESTING SERVICES 11:30:00 214.50 open tester valve 16:43:00 219.72 Fluids to surface 16:45:00 219.75 I .................. 17:00:00 220.00I 32 30 53 0.4 0.4 ii?:i!?~i!?~ii!ii~!~i~i:: 0.4 0.00 0.00 0.00 0.0% 0.40 17:05:00 220.08 Start injecting anti foam 17:30:00 220.50 I 32 50 18:00:00 221.00I 32 30 54 6.7 6.3 i??!i??i!~i~i~ii~ii' 6.7 0.03 0.82 0.03 0.5% 118.1 6.70 25.4 18:00:00 221.00 APl gravity 25.4 18:30:00 221.50 32 15 57 19:00:00 222.00 32 30 57 8.5 1.8 42.8 8.5 0.02 0.43 0.05 1.0% 43.2 8.50 24.6 19:30:00 222.50 32 35 54 20:00:00 223.00 32 35 54 17.5 9.0 215.6 17.4 0.02 0.43 0.07 0.2% 216.0 17.50 25.6 20:30:00 223.50 32 25 53 21:00:00 224.00 32 35 53 21.6 4.1 98.3 21.5 0.00i 0.10 0.07 0.1% 98.4 21.60 21:30:00 224.50 32 35 53 22:00:00 225.00 32 30 53 47.7 26.1 626.4 47.6 0.00 0.00 0.07 0.0% 626.4 47.70 26.25 22:30:00 225.50 32 30 53 22:40:00 225.67 Open choke to 64~64 22:45:00 225.75 Bypass inlet choke 23:00:00 226.00 128 10 64 60.7 13.0 312.0 60.6 0.00 0.00 0.07 0.0% 312.0 60.70 27.1 23:30:00 226.50 128 5 51 6/9/01 0:00:00 227.00 128 15 52 80.5 19.8 475.2 80.4 0.00 0.00 0.07 0.0% 475.2 80.50 27.7 0:30:00 227.50 128 15 52 1:00:00 228.00 128 10 54 97.2 16.7 400.8 97.1 0.00 0.00 0.07 0.0% 400.8 97.20 27.3 1:30:00 228.50 128 10 54 2:00:00 229.00 128 10 55 114.1 16.7 401.5 113.9 0.17 4.06 0.24 1.0% 405.6 114.10 27.8 2:30:00 229.50 i 128 10 55 3:00:00 230.00 128 5 54 133.9 19.8 475.2 133.7 0.00 0.00 0.24 0.0% 475.2 133.90 27.3 3:30:00 230.50 128 3 54; 4:00:00 231.00 128 25 55i 145.5 11.6 278.4 145.3 0.00 0.00 0.24 0.0% 278.4 145.50 27.4 4:30:00 231.50 128 15 55 5:00:00 232.00 128; 25 57 169.9 24.4 585.6 ~ 169.7 0.00 0.00 0.24 0.0% 585.6 169.90 27.3 5:30:00 232.50 128 10 56 6:00:00 233.00 128 10 55 183.5 13.6 326.4 183.3 0.00 0.00 0.24 0.0% 326.4 183.50 27.3 6:30:00 233.50 128 10 55 7:00:00 234.00 128 10 55 192.2 8.6 206.7 191.9 0.09 2.09 0.33 1.0% 208.8 192.20 27.2 7:12:00 234.20 Shut in downhole valve. 7:30:00 234.50 No more flow at surface. 7:50:00 234.83 Shut in ESD valve for pressure build up. 203.1 10.9 i!~iiiiiii!~iii~i~ii 202.8 0.00 ii!??~iii!??~i~i~i!~i 0.330.0% 376.7 203.10 Totals 19.70 I 203.1 202.8 247.0 202..8 0.31 0.41 0.33 0.2% 0.0 203.10 27.1 KWG:RU21PR.xls(Surface Welltest Data) 7/5/01 RU#2 Lower Hemlock DST Flow Rates LpRN Opened 900 BPD ............................................... 800 BPD 700 BPD i ~00 BPD -I- · 500 BPD Flowing against closed surface valve and Nitrogen Pad SurfaCe Opened to flow . . . e Rate during entire 400 BPD Displacing Nitrogen PadI 1 300 BPD t 200 BPD -I ..... 'i flow =444 bbls "Fluid to Surface J" i ' 100 BPD 0 BPD Average Stabilized Flow Rate = 444 bbls Bypassed Choke Flowing to Tanks Afferflow 11:00 14:00 17:00 20:00 23:00 2:00 5:00 KWG:RU21PR.xIs(L.HK WellTest Profile) 7/5/01 Redoubt Unit #2 Lower Hemlock Welltest 55OO 5000 45OO 4000 350O 3000 Elapsed Time (hours) 2500 2000 0 12 24 36 48 60 72 84 96 1500 6/6/01 19:49 6/7/01 7:49 6/7/01 19:49 6/8/01 7:49 6/8/01 19:49 6/9/01 7:49 6/9/01 19:49 '"::"? ?. ;:;;:::.':.'.'~::'~./~.;::..~:::...?~:~::~;'~;;~"':.'~: '..:.,:,, :.':':':.":.:'-'~':;?;:: ?'.:.;: ~ ??'?.::';:.::.':."'":.':-':.,...:.;~::~','. ?~;.;:.':::.~':.-':'; ~:-;.;.;?.;.'.,.."~;~;; ;;~;;~:' ?~::~;~.~ ::'::;:"J:.::':~:,;~::~:~"::~;:/" ?':'?,.;."?::;'~?':'~;:;"::.:::J ~..":'..'..:: :': ;:.....;" -.?..::::'.:: .'::.L'.:.. t";;~ :'-;'...;. ';-"; :." ": '7? :."::.'. ::' ~.':~ :.:..:;::..:';:, :..;':,:.';: ,?'" :'?..j.... '.":7 I-' ':: .'-'...'.. 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' ": . - ~: : ..... :.:"~.L:." ...[ ......:'.:...'.'."..'.:..'. ~' .':::'... :':.: -:! . -. .':": .... ..~ .:- ...: - .... ' '.:.: : : .; .~ ~ ' · · ..?:.;::?..~.~:::~:~...:...:.:::~.::.?~:$~):..?;..::::~.:~.~;.~..::.::.:~;..~:.~.?.....?.~?;?:.:/.:.:..:.:~??..::~?:.?.:...~}~.:.~.~:~.: 108 24O 230 220 0 210 'O 200 ~ 190 03 180 170 Calendar Date and Time 160 6/10/01 7:49 6/10/01 19:49 6/11/01 7:49 KWG:RU#2 LHWelltestData.xls(RU#2LH.WTplot) 7/5/01 Redoubt Unit #2 Lower Hemlock Welltest 42 455O- 4450 435O 425O 4150 4O5O Elapsed Time (hours) 48 54 60 66 72 78 84 3950 , 6/8/01 13:49 6/8/01 19:49 6/9/01 1:49 6/9/01 7:49 6/9/01 13:49 6/9/01 19:49 6/10/01 1:49 6/10/01 7:49 9O 2OO 195 190 --- 185 ~ 180 ~ 175 170 6/10/01 13:49 Calendar Date and Time KWG:RU#2 LHWelltestData.xls(RU#2LH.WTplot (2)) 7/5/01 qmax I 1,929 RU#2 Til Fluid Surfaces (L. HK only) 1,342 RU#2 Flow to Tanks (L. HK only) 1,462 RU#2 Surf SI flow (L. HK only) q (BOPD) pwf pave PI 936 3,658 5,325 0.56 613 3,773 5,325 0.39 444 4,347 5,325 0.45 delta P 1667.15 1552.00 978.00 .......................... flowrate (bOPd) .......................... FBHP 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5300 RU#2 Surf SI flow (L. HK only) 1 929 1 908 1 880 1 844 1 802 1 754 1 698 1 636 1 567 1 491 1 408 1,318 1,222 1,119 1,009 892 769 638 501 357 206 49 16 RU#2 Til Fluid RU#2 Flow to Surfaces (L. HK Tanks (L. HK only) only) 1,342 1,462 1,327 1,446 1,308 1,425 1,283 1,398 1,254 1,366 1,220 1,329 1,182 1,287 1,138 1,240 1,090 1,188 1,037 1,130 980 1,067 917 999 850 926 778 848 702 765 621 676 535 583 444 484 349 380 248 271 143 156 34 37 11 12 Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 258-8600 Fax: (907) 258-8601 MEMORANDUM TO: FROM: DATE: SUBJECT: Gary Carlso ~r~ Paul VVhite ~~;~ July 25, 2001 Annular Returns Analysis - Redoubt Unit #2 Three samples of the oily fluid returns from the Redoubt Unit #2 outer (36" x 13 3/8") annulus were taken on July 6. These samples were sent to CT&E Environmental Services for chemical analysis and comparison with other fluids used in the drilling operation. A gas chromatograph was used to compare the chemical signature of these samples with samples of water-based mud, oil- based mud, Mapco 200 base oil, #2 diesel fuel and crude oil from the Redoubt Unit #2 welltest. This analysis showed that the oily fluid returns most closely matched the crude oil. An analysis was also performed on the water that weeped out with the oily fluids. This water had no significant chlorides or sulfates, thus ruling out it being seawater or produced water. The pH was very high, which would be consistent with water that has been in contact with cement. During the testing of Redoubt Unit #2, approximately 2,013 bbls of crude oil were disposed of into the 9 5/8" x 13 3/8" annulus of the same well. The most logical conclusion is that the oil returns in the outer annulus originated from a micro-annulus, which has slight communication with the primary disposal annulus. Our objective is regain use of this annulus for cuttings disposal. We believe that if this is a micro- annulus it should not be considered a breakdown in our confinement. We expect that there will be from time to time wheepage such as this in any annular disposal operation. Therefor we request approval to return to annular disposal on this well. We plan to closely monitor for any wheepage and report any change in conditions. RECEIVED JUL g 5 Z001 Alaska Oi~ & Gas Cons. Commission Anchorage S:~edoubt Unit #2~nnular disposal\CTE Analysis.doc Page1 of 1 Date Modified: 7/25/01 Date Prepared: 7/20/01 P CT&E Environmental ..;es Inc. Project Letter of Receipt Paee 1 of 2 July 10, 2001 Paul White Forest Oil Corporation 310 K St Suite 700 Anchorage, AK 99501 Dear Paul White: Thank you for your recent request for analytical services. The sample(s) below will be analyzed per your request as outlined below: Project ID: Workorder: Quote No.: Osprey Platform, Cook Inlet 1014163 Client Sample ID: Annulus Well RU2 1 CT&ERef. No.: 1014163001 Matrix: Other Liquids Analysis Requested: DRO/RRO by AK102/AK103 (W) Client Sample ID: Annulus Well RU2 2 CT&E Ref. No.: 1014163002 Matrix: Other Liquids Analysis Requested: DRO/RRO by AK102/AK103 (W) Client Sample ID: Annulus Well RU2 3 CT&ERef. No.: 1014163003 Matrix: Other Liquids Analysis Requested: DRO/RRO by AK102/AK103 (W) Client Sample ID: #4 sample of Batched Waterbase CT&ERef. No.: 1014163004 Matrix: Other Liquids Analysis Requested: DRO/RRO by AK102/AK103 (W) Client Sample ID: '#5 Oil Based Mud CT&ERef. No.: 1014163005 Matrix: Other Liquids Analysis Requested: DRO/RRO by AK102/AK103 (W) Date Collected: Date Received: Date Collected: Date Received: Date Collected: Date Received: Date Collected: Date Received: Date Collected: Date Received: 07/06/01 07/09/01 07/06/01 07/09/01 07/06/01 07/09/01 07/06/01 07/09/01 07/06/01 07/09/01 CT&E Environmental S;i:_.;es Inc. Project Letter of Receipt Pa~e 2 of 2 Client Sample ID: #6 #4 Fuel Oil CT&E Ref. No.: 1014163006 Matrix: Oil/Xylene Miscible Liquid Analysis Requested: DRO/RRO by AK102/AK103 (O) Client Sample ID: #7 #2 Diesel CT&ERef. No.: 1014163007 Matrix: Oil/Xylene Miscible Liquid Analysis Requested: DRO/RRO by AK102/AK103 (O) Client Sample ID: //8 Crude Oil Redoubt//2 CT&ERef. No.: 1014163008 Matrix: Oil/Xylene Miscible Liquid Analysis Requested: DRO/RRO by AK102/AK103 (O) Date Collected: 07/05/01 Date Received: 07/09/01 Date Collected: 07/06/01 Date Received: 07/09/01 Date Collected: 06/14/01 Date Received: 07/09/01 ~ese samples will be disposed of 30 days after completion of final report. For further information or assistance concerning this project please contact your CT&E Project Manager, Mike Priebe, at (907) 562-2343. CT&E Environmental Services Inc. Laboratory Division 200 W. Potter Drive Laboratory Analysis Report Anchorage,AK 99518-1605 Tel: (907) 562-2343 Fax: (907) 561-5301 Web: http://www.cteesi, com Paul White Forest Oil Corporation 310 K St Suite 700 Anchorage, AK 99501 Work Order: Client: Report Date: 1014163 Osprey Platform, Cook Inlet Forest Oil Corporation July 17, 2001 Enclosed are the analytical results associated with the above workorder. As required by the state of Alaska and the USEPA, a formal Quality Assurance/Quality Control Program is maintained by CT&E. A copy of our Quality Control Manual that outlines this program is available at your request. Except as specifically noted, all statements and data in this report are in conformance to the provisions set forth in our Quality Assurance Program Plan. If you have any questions regarding this report or if we can be of any other assistance, please call your CT&E Project Manager at (907) 562-2343. The following descriptors may be found on your report which will serve to further qualify the data. U F B GT D LT Indicates the analyte was analyzed for but not detected. Indicates an estimated value that falls below PQL, but is greater than the MDL. Indicates the analyte is found in the blank associated with the sample. The analyte has exceeded allowable limits. Greater Than Secondary Dilution Less Than Surrogate out of range - 1..R,,E.LI, MIN A RY - ' ~ SGS Member of the SGS Group (Societe Generale de Surveillance) 200 W. Potter Drive, Anchorage, AK 99518-1605- Tel: (907) 562-2343 Fax: (907) 561-5301 3180 Peger Road, Fairbanks, AK 99701-5471 -Tel: (907) 474-8656 Fax: (907) 474-9685 CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By 1014163001 Forest Oil Corporation Osl~re¥ Platform, Cook Inlet Annulus Well RU2 1 Oil/Xylene Miscible Liquid Sample Remarks: 102/103 - Surrogates are not added to oil matrices. Hydrocarbon pattern most consistent with crude oil sample #8. Client PO# Printed Date/Time 07/17/2001 13:40 Collected Date/Time 07/06/2001 0:00 Received Date/Time 07/09/2001 11:19 Technical Director Stephen C. Ede Parameter Results PQL Units Method Allowable Prep Analysis Limits Date Date Init Semivolatile Organic Diesel Range Organics Residual Range Organics GC Fuels Department 769000 480000 U 48000 mg/Kg 480000 mg/Kg AK 102/103 AK 102/103 07/11/01 07/12/01 MCM 07/11/01 07/12/01 MCM Surrogates n-Triacontane-d62 <Surf> 5a Androstane <surr> 5270 ! % 4560 ! % AK102/103 AK102/103 50-150 07/11/01 07/12/01 MCM 50-150 07/11/01 07/12/01 MCM - PRELIMINARY- CT&E Environmental S ..,;es Inc. CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By 1014163002 Forest Oil Corporation Osprey Platform, Cook Inlet Annulus Well RU2 2 Oil/Xylene Miscible Liquid Sample Remarks: 102/103 - Surrogates are not added to oil matrices. Hydrocarbon pattern most consistent with crude oil sample #8. Client PO# Printed Date/Time 07/17/2001 13:40 Collected Date/Time 07/06/2001 0:00 Received Date/Time 07/09/2001 11:19 Technical Director Stephen C. Ede Released By Parameter Results PQL Units Method Allowable Prep Analysis Limits Date Date Init Semivolatile Organic Diesel Range Organics Residual Range Organics GC Fuels Department 673000 599000 U 59900 mg/Kg 599000 mg/Kg AK102/103 AK 102/103 07/11/01 07/11/01 07/12/01 07/12/01 MCM MCM Surrogates n-Triacontane-d62 <Surf> 5a Androstane <surr> 2080 ! % 3810 ! % AK102/103 AK 102/103 50-150 07/11/01 07/12/01 MCM 50-150 07/11/01 07/12/01 MCM - PRELIMINARY- CT&E Environmental S _.,;es Inc. CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By 1014163003 Forest Oil Corporation Osprey Platform, Cook Inlet Annulus Well RU2 3 Oil/Xylene Miscible Liquid Client PO# Printed Date/Time 07/17/2001 13:40 Collected Date/Time 07/06/2001 0:00 Received Date/Time 07/09/2001 11:19 Technical Director Stephen C. Ede ReleasedBy ~~-"~.~ ~ Sample Remarks: 102/103 - Surrogates are not added to oil matrices. Hydrocarbon pattern most consistent with crude oil sample #8. Parameter Results PQL Units Method Allowable Prep Limits Date Analysis Date Init Semivolatile Organic Fuels Department Diesel Range Organics 781000 Residual Range Organics GC 793000 U 79300 mg/Kg 793000 mg/Kg AK 102/103 AK 102/103 07/11/01 07/11/01 07/12/01 07/12/01 MCM MCM Surrogates n-Triacontane-d62 <Surf> 3540 5a Androstane <surr> 3030 ! % ! % AK 102/103 AK 102/103 50-150 07/11/01 07/12/01 MCM 50-150 07/11/01 07/12/01 MCM - P,RIgLIMINARY - CT&E Environmental S ..;es Inc. CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By 1014163004 Forest Oil Corporation Osprey Platform, Cook Inlet g4 sample of Batched Waterbase Oil/Xylene Miscible Liquid Client PO# Printed Date/Time 07/17/2001 13:40 Collected Date/Time 07/06/2001 0:00 Received Date/Time 07/09/2001 11:19 Technical Director Stephen C. Ede Released By ~J~~ Sample Remarks: 102/103 - Surrogates are not added to oil matrices. Hydrocarbon pattern not consistent with oil from annulus samples 1-3. Parameter Results PQL Units Method Allowable Prep Analysis Limits Date Date Init Semivolatile Organic Diesel Range Organics Residual Range Organics GC Fuels Department 703000 617000 U 61700 mg/Kg 617000 mg/Kg AK 102/103 AK102/103 07/11/01 07/12/01 MCM 07/11/01 07/12/01 MCM Surrogates 5a Androstane <surr> n-Triacontane-d62 <Surr> 42.8 ! % 3.6 ! % AK 102/103 AK 102/103 50-150 07/11/01 07/12/01 MCM 50-150 07/11/01 07/12/01 MCM - PREI.AMINARY- CT&E Environrnontal $ ,..~;es Inc. CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By 1014163005 Forest Oil Corporation Osprey Platform~ Cook Inlet #5 Oil Based Mud Oil/Xylene Miscible Liquid Client POg Printed Date/Time 07/17/2001 13:40 Collected Date/Time 07/06/2001 0:00 Received Date/Time 07/09/2001 11:19 Technical Director Stephen C. Ede ReleasedBy ~~-- ~ Sample Remarks: 102/103 - Surrogates are not added to oil matrices. Hydrocarbon pattern not consistent with oil from annulus samples 1-3. Parameter Results PQL Units Method Allowable Prep Analysis Limits Date Date Init Semivolatile Organic Diesel Range Organics Residual Range Organics GC Fuels Department 776000 588000 U 58800 mg/Kg 588000 mg/Kg AK102/103 AK102/103 07/11/01 07/11/01 07/12/01 07/12/01 MCM MCM Surrogates n-Triacontane-d62 <Surf> 5a Androstane <surf> 87.5 % 272 ! % AK102/103 AK102/103 50-150 07/11/01 07/12/01 MCM 50-150 07/11/01 07/12/01 MCM - PRELIMINARY- CT&E Environmental S ,_.,;es Inc. CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By 1014163O06 Forest Oil Corporation Os;~rev Platform, Cook Inlet #6 g4 Fuel Oil Oil/Xylene Miscible Liquid Client PO# Printed Date/Time 07/17/2001 13:40 Collected Date/Time 07/05/2001 0:00 Received Date/Time 07/09/2001 11:19 Technical Director Stephen C. Ede Released By ~j.~ Sample Remarks: DRO - Pattern consistent with a middle distillate slighly heavier than DF#2. DRO/RRO - Surrogate not added to oil matrix. Parameter Results PQL Units Method Allowable Prep Analysis Limits Date Date Init Semivolatile Organic Fuels Department Diesel Range Organics 1510000 108000 mg/Kg Residual Range Organics GC 1080000 U 1080000 mg/Kg AK 102/103 AK 102/103 07/11/01 07/12/01 MCM 07/11/01 07/12/01 MCM Surrogates n-Triacontane-d62 <Surr> 124 % 5a Androstane <surr> 243 ! % AK102/103 AK 102/103 50-150 07/11/01 07/12/01 MCM 50-150 07/11/01 07/12/01 MCM -P.RELIMINARY - CT&E Environmental S ..,;es Inc. CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By 1014163007 Forest Oil Corporation Osprey Platform, Cook Inlet #7 #2 Diesel Oil/Xylene Miscible Liquid Client PO# Printed Date/Time 07/17/2001 13:40 Collected Date/Time 07/06/2001 0:00 Received Date/Time 07/09/2001 11:19 Technical Director Stephen C. Ede ReleasedBy ~C., ~ Sample Remarks: DRO - Pattern consistent with a middle distillate such as DF#2. DRO/P,.RO - Surrogate not added to oil matrix. Parameter Results PQL Units Method Allowable Prep Analysis Limits Date Date Init Semivolatile Organic Diesel Range Organics Residual Range Organics GC Surrogates n-Triacontane-d62 <Surr> 5a Androstane <surr> Fuels Department 897000 535000 U 53500 535000 mg/Kg mg/Kg 18.6 ! % 141 % AK 102/103 AK 102/103 AK 102/103 AK 102/103 07/11/01 07/12/01 MCM 07/11/01 07/12/01 MCM 50-150 07/11/01 07/12/01 MCM 50-150 07/11/01 07/12/01 MCM - PRELIMINARY- CT&E Environmental S _.,;es Inc. CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By 1014163008 Forest Oil Corporation Osore¥ Platform, Cook Inlet #8 Crude Oil Redoubt #2 Oil/Xylene Miscible Liquid Client PO# Printed Date/Time 07/17/2001 13:40 Collected Date/Time 06/14/2001 0:00 Received Date/Time 07/09/2001 11:19 Technical Director Stephen C. Ede Released By ~~'~"- ~ Sample Remarks: DRO/RRO - Surrogate not added to oil matrix. DRO/RRO - Pattern consistent with crude oil. Parameter Results PQL Units Method Allowable Prep Analysis Limits Date Date Init Semivolatile Organic Diesel Range Organics Residual Range Organics GC Fuels Department 402000 459000 U 45900 mg/Kg 459000 mg/Kg AK 102/103 AK 102/103 07/11/01 07/13/01 MCM 07/11/01 07/13/01 MCM Surrogates n-Triacontane-d62 <Surr> 5a Androstane <surr> 927 ! % 413 ! % AK 102/103 AK 102/103 50-150 07/11/01 07/13/01 MCM 50-150 07/11/01 07/13/01 MCM - PRELIMINARY- CT&E Environmental Services, Inc. Sample Name: 1014163001 Date/Time: 07/12/2001 6:06:17 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_005.DAT Front FID Results Name R.T. Area Amount IC Analyst: MCM Units 5 alpha Androstane 16.850 62159 22.787 LC DTC 2!.390 44311 26.326 DRO 4678543 1582.606 PRO 1421106 789.417 DRO AND SURR 4740702 1603.934 RRO AND SURR 1465417 814.032 HH HH ppm ppm Page 2 of 3 (17) CT&E Environmental Services, Inc. Sample Name: 1014163001 Date/Time: 07/12/2001 6:06:17 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution' 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_005. DAT DRO/RRO Analyst: MCM 0.08 0.07 0.06 0,05 0.04 0.03i 0.02 0.01 0 2 4 6 8 10 12 14 16 18 Minutes Page 3 of 3 (18) 20 22 0.08 0.07 0.06 0.05 0.04 0.03 0.02 0.01 2 26 28 CT&E Environmental Services, Inc. Sample Name: 1014163002 Date/Time: 07/12/2001 7:20:09 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_007.DAT Front FID Results Name R.T. Area Amount lC Analyst: MCM Units 5 alpha Androstane 16.848 51924 19.035 LC DTC 21.290 17466 10.377 LC DRO 3287068 1105.168 RRO 1295669 719.738 DRO AND SURR 3338992 1122.984 RRO AND SURR 1313135 729.440 HH HH ppm ppm Page 2 of 3 (23) CT&E Environmental Services, Inc. Sample Name: 1014163002 Date/Time: 07/12/2001 7:20:09 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701 \07 t 201\SDF05030712_007. DAT DRO/RRO Analyst: MCM 0.06 0.05 , 0.04 0.03 0.02 0.01 0 2 4 6 8 10 14 16 18 20 22 24 26 28 Minutes Page 3 of 3 (24) 0.06 I i- 0.05 0.04 0.03 0.02 0.01 CT&E Environmental Services, Inc. Sample Name: 1014163003 Date/Time: 07/12/2001 8:34:01 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_009.DAT Front FID Results Name R.T. Area Amount lC Analyst: MCM Units 5 alpha Androstane 16.842 41335 15.153 LC DTC 21.392 29780 17.693 LC DRO 2894985 970.638 RRO 994935 552.681 DRO AND SURR 2936320 984.821 RRO AND SURR 1024715 569.224 HH HH ppm ppm Page 2 of 3 (29) CT&E Environmental Services, Inc. Sample Name: 1014163003 Date/Time: 07/12/2001 8:34:01 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201 \SDF05030712_009. DAT DRO/RRO Analyst: MCM o.o5ol 0.045 0.040 0.035 0.0301 0.025 0.020 0.015 0.010 0 2 4 6 8 14 16 Minutes Page 3 of 3 (30) 0.050 0.045 0.040 0.035 0.030 - 0.025 0.020 I 0.015 !o.olo 20 22 24 26 21} CT&E Environmental Services, Inc. Sample Name: 1014163004 Date/Time: 07/12/2001 9:47:22 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_011.DAT Front FID Results Name R.T. Area Amount lC Analyst: MCM Units 5 alpha Androstane 16.857 11662 4.275 LC DTC 21.337 608 0.361 LC DRO 3373376 1134.782 RRO 75489 41.934 LC DRO AND SURR 3385038 1138.783 RRO AND SURR 76097 42.272 LC HH HH ppm ppm Page 2 of 3 (35) CT&E Environmental Services, Inc. Sample Name: 1014163004 Date/Time: 07/12/2001 9:47:22 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_011. DAT DRO/RRO Analyst: MCM 0.08 0.07 0.06 0.05 o.o~1 0.03 0.02 J 0.01 t ..... 0.08 0.07 0.06 0.05 0.03 0.02 0.01 4 ~ ~ 1'0 1'2 14 Minutes 16 18 20 22 24 26 28 Page 3 of 3 (36) CT&E Environmental Services, Inc. Sample Name: 1014163005 Date/Time: 07/12/2001 10:24:01 PM Method: C:\EZChrom Elite\Pr°jects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_012.DAT Front FID Results Name R.T. Area Amount lC Analyst: MCM Units 5 alpha Androstane 16.852 74219 27.209 DTC 21.217 14723 8.747 LC DRO 3837894 1294.165 RRO 301615 167.546 LC DRO AND SURR 3912113 1319.631 RRO AND SURR 316338 175.724 LC HH HH ppm ppm Page 2 of 3 (38) CT&E Environmental Services, Inc. Sample Name: 1014163005 Date/Time: 07/12/2001 10:24:01 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_012. DAT DRO/RRO Analyst: MCM O.lOi 0.09 0.08 0.07 0.06 0.05 0.04 0.03 0.02 0.01 1i- I 0 2 4 8 1 '0 1 '2 Minutes Page 3 of 3 (39) LO.lO 0.09 0.08 0.07 0.06 0.05 0.03 0.01 [ ,,--~ '--T .... ~ ..... r'- ......... I-' .... r .... ~ ! 2'0 22 24 26 28 CT&E Environmental Services, Inc. Sample Name: 1014163006 Date/Time: 07/12/2001 11:00:42 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_013.DAT Front FID Results Name R.T. Area Amount lC Analyst: MCM Units 5 alpha Androstane 16.847 66251 24.287 LC DTC 21.390 20922 12.430 LC DRO 4088517 1380.158 RRO 736945 409.369 DRO AND SURR 4154768 1402.890 RRO AND SURR 757867 420.991 HH HH ppm ppm Page 2 of 3 (4 l) CT&E Environmental Services, Inc. Sample Name: 1014163006 Date/Time: 07/12/2001 11:00:42 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_013.DAT DRO/RRO Analyst: MCM - -- 0.08 0.08 0.07 0.06 0.05 0.04 0.03 0.02 0.01 0 2 4 8 10 12 T 1''4 ' ' '16 Minutes Page 3 of 3 (42) 18 0.07 0.06 0.05 0.04 0.03 0.02 - 0.01 CT&E Environmental Services, Inc. Sample Name: 1014163007 Date/Time: 07/12/2001 11:37:18 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_014.DAT Front FID Results Name R.T. Area Amount IC Analyst: MCM Units 5 alpha Androstane 16.875 38401 14.078 LC DTC 21.290 3138 1.864 LC DRO 4918648 1664.990 PRO 113936 63.291 LC DRO AND SURR 4957049 1678.166 PRO AND SURR 117074 65.034 LC HH HH ppm ppm Page 2 of 3 (44) CT&E Environmental Services, Inc. Sample Name: 1014163007 Date/Time: 07/12/2001 11:37:18 PM Method: C:\EZChrom Elite\Projects\Public\SD\Meth°d\SDF05030503.met Dilution: 1 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201 \SDF05030712_014. DAT DRO/RRO Analyst: MCM 0.12 0.10 0.08 0.04 0.02 0.00 j ........ 0 ~2 '~4 1'6 Minutes Page 3 of 3 (45) 18 20 0,12 0.10 0.08 0,06 0.02 i o.oo ...... ~-~., ..... , ...... ~ ..... 2'2 24 26 28 CT&E Environmental Services, Inc. Sample Name: 1014163008*5 Date/Time: 07/13/2001 3:33:24 PM Method: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 5 Sample File: C:\EZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_026. DAT Front FID Results Name R.T. Area Amount lC Analyst: MCM Units 5 alpha Androstane 16.848 22531 41.299 LC DTC 21.393 31203 92.693 LC DRO 2595648 4339.653 RRO 962047 2672.062 DRO AND SURR 2618179 4378.307 RRO AND SURR 993250 2758.728 HH HH ppm ppm Page 2 of 3 N CT&E Environmental Services, Inc. Sample Name: 1014163008'5 Date/Time: 07/13/2001 3:33:24 PM Methed: C:\EZChrom Elite\Projects\Public\SD\Method\SDF05030503.met Dilution: 5 Sample File: C:\F_.ZChrom Elite\Projects\Public\SD\Data\0701\071201\SDF05030712_.026.DAT DRO/RRO Analyst: MCM 0.045 0,040 0.035 0.030 0.025 O.OZO 0,015 0.010 6 8 1 I 16 18 Page 3 of 3 .045 · 0.040 RE: RU #2 Annular injection Subject: Date: From: To: CC: RE: RU #2 Annular injection Thu, 12 Jul 2001 10:39:51 -0600 Paul White <PDWhite~forestoil.com> 'Julie Heusser' <julie_heusser~admin.state.ak.us> 'Wendy Mahan' <Wendy_Mahan@admin.state.ak.us>, Gary Carlson <GECarlson@forestoil.com>, John Amundsen <JDAmundsen@forestoil.com>, Camille O Taylor <cammy_taylor@admin.state.ak.us>, D an Seamount <dan_seamount@admin. state, ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us> Wendy, I spoke with CT&E regarding the oil sample analysis this morning. I was told they could have them sometime tomorrow. Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~forestoil.com ..... Original Message ..... From: dulie Heusser [SMTP.julie_heusser~admin.state. ak. us] Sent: Tuesday, July 10, 2001 2:50 PM To: Paul White Cc: 'Wendy Mahan'; Gary Carlson; John Amundsen; Camille 0 Taylor; Dan Seamount; Thomas E Maunder Subject: Re: R U #2 Annular injection Importance: High Dear Mr. White, Because there appears to be some confusion around the Commission's position regarding continuing annular disposal at R U #2, I would like to take a minute to restate the position the Commission developed when we met with you and Mr. Carlson on July 3, 2001. On July 3, 2001, the Commission gave its approval for Forest Oil to dispose of the 600 + bbls of slurry that was stored at that time on the Osprey Platform. The Commission requested that Forest Oil have lab analyses performed on the various fluids injected and/or returned to surface as these lab 1 of 4 7/26/01 11:37 AM RE: RU #2 Annular injection > results > wouM be required before a determination regarding the status offitrther > > disposal on R U #2 can be made. > > As you/oww, the Commission cannot authorize annular disposal operations > when there are questions whether the waste is being adequately confined > and/or if the disposal operation will cause (or has caused) drilling waste > to: > (a) surface; (b) impair the mechanical integrity of any well; (c) damage a > producing or potentially producing formation or (d) possibly contaminate > sources offresh water. The Commission has serious concerns, shared > (no doub0 by Forest Oil, regarding the advisability of continuing annular > disposal operations on R U #2. > > If Forest is operationally unable to wait for the requested lab results, > Forest > Oil will need to provide the Commission with a convincing > technical/geological > analysis demonstrating why the recent events on R U #2 are not a case of >fluid > returning to surface that wouM require the cessation of all future > annular > disposal operations on R U #2. > > Please do not hesitate to contact Wendy Mahan (793-1236) or Tom Maunder > (793-1250) shouM you have additional questions re the Commission's > expectations. > > Sincerely, > > Julie Heusser > Commissioner > > > Paul White wrote: > > > Wendy, I apologize for the miscommunication. I reviewed your letter of > the > > 4th and interpreted it to mean we had approval to continue. I checked > with > > CT&E and it will be at least a week before they have the analysis > complete. 2 of 4 7/26/01 11:37 AM RE: RU #2 Annular injection > > At this time it appears we may not have an ongoing problem. > like We would > to continue disposal at least on an interim basis until the analysis is > complete. We will, of course, continue to closely monitor and report any > discrepiencies. Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~forestoil, com > > ..... Original Message ..... > > From: Wendy Mahan [SMTP: Wendy_Mahan@admin.state. ak. us] > > Sent: Monday, July 09, 2001 11.'37 AM > > To: Paul White > > Cc: Gary Carlson; John Amundsen; Camille 0 Taylor; Dan Seamount; Julie > > Heusser; Thomas E Maunder > Subject: Re: R U #2 Annular injection Paul, 600 .Thank you for the notification of your injection activities. However, the Commission was under the impression that after you injected the bbls slurry~200 bbl fluid stored on the platform, future injections > > would cease until the test results were evaluated. Please do not inject > > any more fluids into the R U #2 annulus until your test results are > > returned and you have a chance to interpret the results. > > Please feel free to call either Tom Maunder or myselfifyou have any > > further questions. Wendy Mahan Natural Resource Manager Paul White wrote: We completed batch #49 annular disposal on R U #2. > > > Wendy, disposed We 3 of 4 7/26/01 11:37 AM RE: RU #2 Annular injection >>>of21 > > > > bbls. pre-flush, 360.5 bbls. sluro; and 271 bbls. post-flush. All > rates > > > and >is > > > being > > > > monitored 24 hfs~day. > > > > Thanks, > > > > Paul D. White, Drilling.Manager > > > > Forest Oil Corp. > > > > 907-868-2134 > > > > pdwhite~_forestoil, com > > pressures ~4,ere normal and there were no drips of any kind. Annulus 4 of 4 7/26/01 11:37 AM Re: RU #2 Annular injection Subject: Re: RU #2 Annular injection Date: Tue, 10 Jul 2001 14:49:49 -0800 From: Julie Heusser <julie_heusser@admin.state.ak.us> To: Paul White <PDWhite~forestoil.com> CC: 'Wendy Mahan' <Wendy_Mahan~admin.state.ak.us>, Gary Carlson <GECarlson~forestoil.com>, John Amundsen <JDAmundsen~forestoil.com>, Camille O Taylor <cammy_taylor~admin.state.ak.us>, Dan Seamount <dan_seamount@admin. state.ak.us>, Thomas E Maunder <tom_maunder~admin.state.ak.us> Dear Mr. White, Because there appears to be some confusion around the Commission's position regarding continuing annular disposal at RU #2, I would like to take a minute to restate the position the Commission developed when we met with you and Mr. Carlson on July 3, 2001. On July 3, 2001, the Commission gave its approval for Forest Oil to dispose of the 600 + bbls of slurry that was stored at that time on the Osprey Platform. The Commission requested that Forest Oil have lab analyses performed on the various fluids injected and/or returned to surface as these lab results would be required before a determination regarding the status of further annular disposal on RU #2 can be made. As you know, the Commission cannot authorize annular disposal operations when there are questions whether the waste is being adequately confined and/or if the disposal operation will cause (or has caused) drilling waste to: (a) surface; (b) impair the mechanical integrity of any well; (c) damage a producing or potentially producing formation or (d) possibly contaminate sources of fresh water. The Commission has serious concerns, shared (no doubt) by Forest Oil, regarding the advisability of continuing annular disposal operations on RU #2. If Forest is operationally unable to wait for the requested lab results, Forest Oil will need to provide the Commission with a convincing technical/geological · analysis demonstrating why the recent events on RU #2 are not a case of fluid returning to surface that would require the cessation of all future annular disposal operations on RU #2. Please do not hesitate to contact Wendy Mahan (793-1236) or Tom Maunder (793-1250) should you have additional questions re the Commission's expectations. Sincerely, Julie Heusser Commissioner I of 3 7/26/01 11:37 AM Re: RU #2 Annular injection Paul White wrote: > Wendy, I apologize for the miscommunication. I reviewed your letter of the > 4th and interpreted it to mean we had approval to continue. I checked with > CT&E and it will be at least a week before they have the analysis complete. > At this time it appears we may not have an ongoing problem. We wouM like > to continue disposal at least on an interim basis until the analysis is > complete. We will, of course, continue to closely monitor and report any > discrepiencies. > Paul D. White, Drilling Manager > Forest Oil Corp. > 907-868-2134 > pdwhite~_forestoil, com Original Message ..... From: Wendy Mahan [SMTP: Wendy_Mahan~admin.state. ak. us] Sent: Monday, July 09, 2001 ll:37AM To: Paul White Cc: Gary Carlson; John Amundsen; Camille 0 Taylor; Dan Seamount; dulie Heusser; Thomas E Maunder Subject: Re: R U #2 Annular injection Paul, Thank you for the notification of your injection activities. However, the Commission was under the impression that after you injected the 600 bbls slurry~200 bbl fluid stored on the platform, future injections wouM cease until the test results were evaluated. Please do not inject any more fluids into the R U #2 annulus until your test results are returned and you have a chance to interpret the results. Please feel free to call either Tom Maunder or myself if you have any further questions. Wendy Mahan Natural Resource Manager > > Paul White wrote: 2 of 3 7/26/01 11:37 AM Re: RU #2 Annular injcction > Wendy, We completed batch #49 annular disposal on R U #2. We disposed of 21 > bbls. pre-flush, 360.5 bbls. slur~3; and 271 bbls. post-flush. All rates and > pressures were normal and there were no drips of any kind. Annulus is being > monitored 24 hfs~day. Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~_forestoil, com 3 of 3 7/26/01 11:37 AM RE: RU #2 Annular injection Subject: RE: RU #2 Annular injection Date: Mon, 9 Jul 2001 17:18:38 -0600 From: Paul White <PDWhite@forestoil.com> To: 'Wendy Mahan' <Wendy_Mahan@admin.state.ak.us>, Paul White <PDWhite~forestoil.com> CC.' Gary Carlson <GECarlson@forestoil.com>, John Amundsen <JDAmundsen@forestoil.com>, Camille O Taylor <cammy taylor~admin.state.ak.us>, Dan Seamount <dan_seamount~admin.state.ak.us>, Julie Heusser <julie_heusser@admin.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us> Wendy, I apologize for the miscommunication. I reviewed your letter of the 4th and interpreted it to mean we had approval to continue. I checked with CT&E and it will be at least a week before they have the analysis complete. At this time it appears we may not have an ongoing problem. We would like to continue disposal at least on an interim basis until the analysis is complete. We will, of course, continue to closely monitor and report any discrepiencies. Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~forestoil.com > ..... Original Message ..... > From: Wendy Mahan [SMTP: Wendy_Mahan@admin.state. ak. us] > Sent: Monday, July 09, 2001 ll:37AM > To: Paul White > Cc: Gary Carlson; John Amundsen; Camille 0 Taylor; Dan Seamount; Julie > Heusser; Thomas .E.Maunder > Subject: Re: R U #2 Annular injection > Paul, > Thank you for the notification ofyour injection activities. However, > the Commission was under the impression that after you injected the 600 > bbls slurry~200 bblfluid stored on the platform, future injections > wouM cease until the test results were evaluated. Please do not inject > any more fluids into the R U (42 annulus until your test results are > returned andyou have a chance to interpret the results. > Please feel free to call either Tom Maunder or myselfifyou have any > further questions. I of 2 7/26/01 11:37 AM RE: RU #2 Annular injection :> Wendy Mahan Natural Resource Manager Patti I4/hite wrote: > Wendy, We completed batch #49 annular disposal on R U #2. We disposed of 21 > bbls. pre-flush, 360.5 bbls. slun3, and 271 bbls. post-flush. All rates and > pressures were normal and there were no drips of any kind. Anmdus is being > monitored 24 hfs~day. Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~_forestoil, corn 2 ot"2 7/26/01 11:37 AM Re: RU #2 Annular injection Subject: Date: From: Organization: To: CC: Re: RU #2 Annular injection Mon, 09 Jul 2001 11:36:57 -0800 Wendy Mahan <Wendy_Mahan~admin.state.ak.us> doa-aogcc Paul White <PDWhite~forestoil.com> Gary Carlson <GECarlson~forestoil.com>, John Amundsen <JDAmundsen~forestoil.com>, Camille O Taylor <cammy_taylor~admin.state.ak.us>, Dan Seamount <dan_seamount~admin.state.ak.us>, Julie Heusser <julie_heusser~admin.state.ak.us>, Thomas E Maunder <tom_maunder~admin. state, ak.us> Paul, Thank you for the notification of your injection activities. However, the Commission was under the impression that after you injected the 600 bbls slurry/200 bbl fluid stored on the platform, future injections would cease until the test results Were evaluated. Please do not inject any more fluids into the RU #2 annulus until your test results are returned and you have a chance to interpret the results. Please feel free to call either Tom Maunder or myself if you have any further questions. Wendy Mahan Natural Resource Manager Paul White wrote: Wendy, We completed batch #49 annular disposal on RU #2. We disposed of 21 bbls. pre-flush, 360.5 bbls. slurry and 271 bbls. post-flush. All rates and pressures were normal and there were no drips of any kind. Annulus is being monitored 24 hfs~day. Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~_fforestoil, com 1 of 1 7/26/01 11:41 AM RU #2 Annular injection Subject: RU #2 Annular injection Date: Mon, 9 Jul 2001 10:18:00 -0600 From: Paul White <PDWhite@forestoil.com> To: 'Wendy Mahan' <Wendy_Mahan@admin.state.ak.us> CC: Gary Carlson <GECarlson~forestoil.com>, John Amundsen <JDAmundsen~forestoil.com> Wendy, We completed batch #49 annular disposal on RU #2. We disposed of 21 bbls. pre-flush, 360.5 bbls. slurry and 271 bbls. post-flush. All rates and pressures were normal and there were no drips of any kind. Annulus is being monitored 24 hrs/day. Thanks, Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~forestoil.com I of 1 7/26/01 11:37 AM July 6, 2001 Paul White Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Re: Annular Disposal Waiver Request to Exceed Volume Limitation in RU #2 Dear Mr. White: We have reviewed your June 22, 2001 request for a waiver to 20 AAC 25.080(d)(1). The waiver would allow Forest to dispose of a volume of fluids greater than 35,000 barrels into the annular space of well RU #2. If approved, the waiver would allow the injection of up to 30,000 additional barrels of waste until either the RU #D1 or RU #3 well annuli are approved by the Commission for annular disposal. The additional 30,000 barrels of waste fluids would be disposed of during an additional 90-day period. No other annuli are currently available on the Osprey platform, and oil-based fluids generated from drilling activities may not be discharged from the platform. Forest is currently drilling the RU #D 1 well, and has applied for both freshwater aquifer exemption and disposal injection orders to enable disposal of Class II wastes into the RU #D 1 well. If Forest is not permitted to dispose of waste into the RU #2 annulus, the waste must be transported to shore and stored until either another annulus or a Class II well become available for disposal of these wastes. The Commission concludes that an additional 30,000 barrels of fluids generated from drilling on the Osprey platform may be injected into the RU #2 annulus for an additional 90-day period. Sincerely, Cammy Taylor Chair Forest Oil Corporation Alaska Division 310 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITTAL RECEIVED JUL 0 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Date: July 6, 2001 To: Phone: Lisa Weepie/Howard Oakland AOGCC 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Barbara Murray Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Phone: (907) 258 - 8600 FAX: (907) 258 - 8601 TRANSMITTAL DESCRIPTION ~.~VVWell MRU-7 ,~t,~,~JM RU-7st ~)\"~ ¥~NMRU-7 .... WMRU-7st ~..'WMRU-7 APl Number Description Data From: 50-133-20500-00 1-Final Well Report Epoch 50-133-20500-01 1-Final Well Repdrt ,~ Epoch 50-133-20500-00 1- velum 2"=100' MD Mudlog 50-133-20500-01 1-velum 2"=100' MD Mudlog Epoch Epoch 50-133-20500-00 1- CD Final Well Data Epoch ~.WMRU-7st 50-133-20500-01 1- CD Final Well Data Epoch '"WMRU-7st 50-133-20500-01 2 boxes - Dryed cuttings for WMRU-7st Epoch .... Ru -2 50-733-20501-00 2 boxes - Dryed cuttings for RU #2 Epoch 50-733-20501-00 1- Final Well Report Epoch -2 -2 50-733-20501-00 l-velum 2"=100' MD Mudlog Epoch -2 50-733-20501-00 1- CD Final Well Data Epoch -'Ru -2 50-733-20501-00 1 film -Gamma Ray, Neutron-run 4(236'-3685') Schlumberger : RU -2 50-733-20501-00 1 film-Repeat Formation Tester-run 4(14424'-15164') Schlumberger RU -2 50-733-20501-00 1 film -Dipole Shear Sonic-run 4(14356'-15338') Schlumberger ,.RU -2 50-733-20501-00 1 film-Array Induction, D, N, GR - PE - run 4(14356'-15338') RU -2 50-733-20501-00 1 film-Array Induction Dipole Shear Sonic -run 4 (14356'-15338') ' RU -2 50-733-20501-00 1 film-Caliper Log -run 4 (14356'-15338') ', RU -2 50-733-20501-00 1 film-Combinable Magnetic Resonance Tool-run 4 (14400'-15200') ,Ru -2 ,.I .Ru -2 50-733-20501-00 1 film-Ultrasonic Borehole Imager -run 5(14360-15050) 50-733-20501-00 1 film-Ultrasonic Imaging Tool-run 5 (14126-15234) :~.'RU -2 50-733-20501-00 1 film-Cased Hole Formation Resistivity Gamma Ray- run 5(13800-14600) ., RU -2 50-733-20501-00 1 film-Cement Bond Tool-run 5(14126-15234) ?R.u -2 50-733-20501-00 1 film-Temperature Log Baseline and Post Injection (100-9000) ""RU -2 50-733-20501-00 1 film-Array Induction, D, N, GR, Caliper- PE- run 3 (12900-14695) RU -2 50-733-20501-00 1 film-Array Induction, Sonic DT Compressional, GR (12900-14695) RU2 and WMRU-7st to AOGCC.xls/Pagel Date Modified:7/6/01 Date Prepared: 12/6/00 bk Rt.~'2 "" 50-733-20501-00 1 ~.U -2 50-733-20501-00 ./RU -2 50-733-20501-00 J~U -2 50-733-20501-00 ~,'U -2 50-733-20501-00 ~..R0 -2 50-733-20501-00 ...RU -2 50-733-20501-00 ..... RU -2 50-733-20501-00 ,.-RU -2 50-733-20501-00 ;...R'u -2 50-733-20501-00 1 ~-'RU -2 50-733-20501-00 1 ,--RU.-2 50-733-20501-00 1 ,.,R'u -2 50-733-20501-00 I ...... RU -2 50-733-20501-00 ...... RU -2 50-733-20501-00 ...... "RU -2 50-733-20501-00 1 ,'"'RU -2 ;'15,'U -2 50-733-20501-00 1 50-733-20501-00 1 50-733-20501-00 1 film-Dipole Sonic Imaging (12900'-14695') 1 film-Dipole Shear Sonic Log, Gamma Ray (9019'-13209') 1 film-Ultrasonic Borehole Imager, Gamma Ray run 3(9019-13209) 1 film-PE-Arra¥ Induction, Density, Neutron, GR (8800'-13209') I film-Dipole Shear Sonic Image -run2 (3212'-8976') 1 film-Array Induction, Desnity, Neutron, GR, Caliper- PE (3212-8976) 1 film-Array Induction Dipole Shear Sonic (3212-8976) 1 film-Caliper Gamma Ray (3212'-8976') 1 paper- Repeat Formation Tester (14424'-15164') paper- Gamma Ray, Neutron (236'-3685') -5/18/01 paper- Array Induction, Sonic DT Compressional, GR (12900-14695) paper- Cement Bond Tool (14126-15234) -5/28/01 paper- Combinable Magnetic Resonance Tool (14400'-15200') 5/18/01 1 paper- Temperature Log Baseline and Post Injection (100'-9000') 5/2/01 1 paper- Cased Hole formation Resistivity, Gamma Ray (13800'-14600') paper- Caliper, Gamma Ray (3213'-8976') 3/15/01 paper- Ultrasonic Borehole Imager (14360'-150501) 5/18/01 paper- Ultrasonic Imaging Tool (14126'-15234') 5/28/01 paper- Ultrasonic Borehole Imager, Gamma Ray (9019'-13209') ,~.RU-2 50-733-20501-00 1 paper ......... RU-2 50-733-20501-00 1 paper ':~"Ru -2 50-733-20501-00 1 paper ?.R'~-2 50-733-20501-00 1 paper ........ RU - 2 50-733-20501-00 1 paper ~,..,'R'U- 2 50-733-20501-00 1 ~ RU-2 50-733-20501-00 1 - Dipole Shear Sonic (14356'-15338') 5/18/01 - Dipole Shear Sonic Log, Gamma Ray (9019'-13209') 4/9/01 - Dipole Sonic Imaging (12900'-14695') 4/26/01 - Dipole Shear Sonic Image (3212'-8976') 3/15/01 - Array Induction, Dipole Shear Sonic (14356'-15338') 5/18/01 paper - Array Induction, Dipole Shear Sonic (3212'-8976') 3/15/01 paper-Array Induction, Density, Neutron, GR, Cai- PE (3212'-8976')-3/15/01 ..... RU -2 50-733-20501-00 1 paper-Array Induction, D, N, Gr, Cai-Platform Express (8800'-13209')-419101 .... RU -2 50-733-20501-00 1 paper-Array Induction, D,N,Gr,Cal-Platform Express(12900'-14695')-4/26/01 ~:...RU -2 50-733-20501-00 1 paper-Array Induction, D,N,Gr,CaI-Platform Express(14356'-15338')5/18/01 ...... Ru -2 50-733-20501-00 .~-i5, U - 2 50-733-20501-00 I paper - Caliper Log (14356'-15338') - 5/18/01 1 CD - UBI Break out Data (8998'-15036') - 5/7/01 ?I~U- 2 50-733-20501-00 1 CD - AIT/PEX./DSI data (12770'-14717') - 4/26/01 PDS format 50-733-20501-00 1 CD - Open Hole Logs - to 9000' '~'"Ru -2 50-733-20501-00 1 notebook - DST and RFT testing Data Please sign below to acknowledge receipt. IReturned to Forest Oil Accepted By: RU2 and WMRU-7st to AOGCC.xls/Pagel Date: Date ' RECEIVED JUL 0 Naska Oil & Gas Cons. Commission Anchorage Date Modified:7/6/01 Date Prepared: 12/6/00 bk RE: RU #2 Requ~t to exceed 35,000 bbl limitation Subject: RE: RU #2 Request to exceed 35,000 bbl limitation Date: Fri, 6 Jul 2001 10:09:38 -0600 From: Paul White <PDWhite~forestoil.com> To: 'Wendy Mahan' <Wendy_Mahan~admin.state.ak.us> CC: Gary Carlson <GECarlson~forestoil.com>, John Amundsen <JDAmundsen~forestoil.com> We would like to have an exemption to exceed the 35,000 bbl. limitation by 30,000 bbls. This, of course includes the seawater used as pre-flush and post flush. We would like this exemption for the period of 90 days. At that time we should be able to use RU #3 or D-1 for drilling waste disposal. Thank you very much, Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite@forestoil.com 3> 3> 3> 3> 3> 3> 3> 3> 3> 3> 3> 3> 3> ..... Original Message ..... From: Wendy Mahan [SMTP: Wendy_Mahan@admin.state. ak. us] Sent: Thursday, July 05, 2001 8:55 AM To: Paul White Subject: Re: RU #2 Request to exceed 35,000 bbl limitation Paul, We can not "exempt" the seawater because it is defined in our regulations. According to 20 AAC 25.080(h)(1), it becomes part of the drilling waste. We can only give exemptions for 0 duration of disposal, 2) 35,000 bbl limitation, 3) to allow injection into a hydrocarbon-bearing stratum, or 4) into a well located on a different pad or platform. The operator has the burden in each of these cases of providing sufficient evidence that complying with the requirements are imprudent. Please provide an estimated total volume of muds, cuttings and seawater, and expected duration. I will continue work on your request as soon as I receive that information. Wendy Paul White wrote: > > Wendy, I would like to be able to exempt the seawater from the calculation > and consider only drilling waste and mud. This should provide us with I of 2 7/26/01 11:36 AM RE: RU #2 Request to exceed 35,000 bbl limitation > > adaquate capaciO,. We wouM plan to use the annulus in well #3 next. > When > > and if we are forced into zero drilling waste discharge by EPA we might > have > > to reconsider this. > > Thanks, > > Paul D. White, Drilling Manager > > Forest Oil Corp. > > 907-868-2134 > > pdwhite~forestoil, com ..... Original Message ..... From: Wendy Mahan [SMTP: Wendy_Mahan~admin. state, ak. us] Sent: Thursday, July 05, 2001 8:02 AM To: Paul White Subject: RU #2 Request to exceed 35,000 bbl limitation >> Mr. White, Could you provide an estimated volume and duration for the proposed > exceedence of the 35,000 bbl limitation for the RU #2 annular disposal > program ? > Thanks, > Wendy Mahan 2 of 2 7/26/01 11:36 AM RU #2 annular disposal Subject: RU//2 annular disposal Date: Fri, 6 Jul 2001 17:42:34 -0600 From: Paul White <PDWhite@forestoil.com> To: 'Wendy Mahan' <Wendy_Mahan~admin.state.ak.us> CC: Gary Carlson <GECarlson~forestoil.com>, John Amundsen <JDAmundsen~forestoil.com> Wendy, We completed injection/~48 this morning. We injected 21 bbls. pre-flush followed by 479 bbls. of slurried cuttings and chased with 262 bbls. of seawater. The annulus dripped at 13 minutes per cup for a total of 3 quarts fluid. We are estimating approximately 2 tablespoons of oil on top. I have taken the samples to CT&E for fingerprinting and should have results late next week. If you have any questions please give me a call. Regards, Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite@forestoil.com 1 of I 7/26/01 11:36 AM Re: RU #2 Request to exceed 35,000 bbl limitation Subject: Re: RU #2 Request to exceed 35,000 bbl limitation Date: Thu, 05 Jul 2001 08:55:25 -0800 From: Wendy Mahan <Wendy_Mahan~admin.state.ak.us> Organization: doa-aogcc To: Paul White <PDWhite~forestoil.com> Paul, We can not "exempt" the seawater because it is defined in our regulations. According to 20 AAC 25.080(h)(1), it becomes part of the drilling waste. We can only give exemptions for 1) duration of disposal, 2) 35,000 bbl limitation, 3) to allow injection into a hydrocarbon-beating stratum, or 4) into a well located on a different pad or platform. The operator has the burden in each of these cases of providing sufficient evidence that complying with the requirements are imprudent. Please provide an estimated total volume of muds, cuttings and seawater, and expected duration. I will continue work on your request as soon as I receive that information. Thanks, Wendy Paul White wrote: > > > > > > > > > > > > > > > > > > > > > > Wendy, I wouM like to be able to exempt the seawater from the calculation and consider only drilling waste and mud. This shouM provide us with adaquate capacity. We wouM plan to use the annulus in well #3 next. When and if we are forced into zero drilling waste discharge by EPA we might have to reconsider this. Thanks, Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~forestoil, corn > > > > > > > > > ..... Original Message ..... From: Wendy Mahan [SMTP: Wendy_Mahan~admin.state. ak us] Sent: Thursday, duly 05, 2001 8:02 AM To: Paul White Subject: RU #2 Request to exceed 35,000 bbl limitation Mr. White, Could you provide an estimated volume and duration for the proposed exceedence of the 35,000 bbl limitation for the RU #2 annular disposal ! of 2 7/26/01 11:36 AM Re: RU #2 Request to exceed 35,000 bbl limitation > > program ? > > Thanks, > > WendyMahan 2 of 2 7/26/01 11:36 AM RE: RU #2 Request to exceed 35,000 bbl limitation Subject: RE: RU #2 Request to exceed 35,000 bbl limitation Date: Thu, 5 Jul 2001 10:23:11 -0600 From: Paul White <PDWhite~forestoil.com> To: 'Wendy Mahan' <Wendy_Mahan@admin.state.ak.us> CC: Gary Carlson <GECarlson~forestoil.com>, John Amundsen <JDAmundsen@forestoil.com>, Rob Stinson <RDStinson@forestoil.com> Wendy, I would like to be able to exempt the seawater from the calculation and consider only drilling waste and mud. This should provide us with adaquate capacity. We would plan to use the annulus in well #3 next. When and if we are forced into zero drilling waste discharge by EPA we might have to reconsider this. Thanks, Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite@forestoil.com > Original .Message ..... From: Wendy Mahan [SMTP: Wendy_Mahan~admin.state. ak. us] Sent: Thursday, July 05, 2001 8:02 AM To: Paul lVhite Subject: R U #2 Request to exceed 35,000 bbl limitation Mr. l~hite, Could you provide an estimated volume and duration for the proposed exceedence of the 35,000 bbl limitation for the RU #2 annular disposal program ? Wendy Mahan 1 of I 7/26/01 11:36 AM Re: RU #2 Annular disposal Subject: Date: From: To: CC: Re: RU #2 Annular disposal Wed, 4 Jul 2001 12:57:20 -0800 "Paul and Nancy White" <pdwhite~gci.net> "Wendy D Mahan" <wendy_mahan~admin.state.ak.us>, "Paul White" <PDWhite~forestoil.com> "Gary Carlson" <GECarlson~forestoil.com>, <cammy_taylor~admin.state.ak.us>, <dan_seamount@admin.state.ak.us>, <julie_heusser@admin.state.ak.us>, <tom_maunder~admin.state.ak.us> Wendy, We disposed of 600 bbls. of slurried cuttings and 200 bbls. of liquid mud in disposal batch g47 (the batch following our meeting on July 3rd.) The RU #2 annulus dripped at a rate of one cup in 7 minutes during pumping. The total fluid was <1 1/2 gal. with a thin covering ofoil (indentical to first batch). We have collected samples of all fluids (oil base mud, slurried mud, dripped fluid w/oil and whole mud) these samples will be in Anchorage on morning of July 5th. We will make arrangements to have an analysis done and report our findings ASAP. Thanks, Paul White home 243-8959 cell 242-3305 work 868-2134 ..... Original Message ..... From: Wendy D Mahan <wendy_mahan~admin.state.ak.us> To: Paul White <PDWhite~forestoil.com> Cc: Gary Carlson <GECarlson~forestoil.com>; <pdwhite@gci.net>; <cammy_taylor@admin.state.ak.us>; <dan_seamount~admin.state.ak.us>; <julie_heusser~admin.state.ak.us>; <tom_maunder~admin.state.ak.us> Sent: Wednesday, July 04, 2001 6:51 AM Subject: Re: RU #2 Annular disposal 3> > Mr. White, In addition to testing any fluid from the annular weep, per discussions with the Commissioners you also agreed to test samples of the diesel used in the oil-based mud and produced crude. We expect that these samples will also be sent for testing on .Thursday. You have the Commission's permission to continue disposing of the slurried muds and cuttings, with careful monitoring and immediate reporting if any fluids exhibiting a sheen appear in the annulus. Please feel free to call or email me if you have any additional concerns or questions. Wendy Mahan Natural Resource Manager 1 of 3 7/26/01 11:36 AM Re: RU #2 Annular disposal i' > ..... Original .Message ..... > From: Patti White <PDWhite~forestoil. com> > Date: Tuesday, duly 3, 2001 6:56 pm > Subject: R U #2 Annular disposal Dear Wendy, Thanks for meeting with Ga~y and ~nyself to discuss the occttrance of oil skim on the fluid from the RU #2 annulus. We reported that at 0300 hfs on 7/3/01 the 36"X 13 3/8" annulus wept a small ammount offluid. (<2 1/2 > > gals.) The > > fluid has an unidentified oil sheen on it. We do not know the > > origin of this oil. In reporting this we are requesting that we continue to dispose of slurried mud and cuttings and obtaining samples of any fluids that appear in the annulus. We will send these samples to a lab on Thursday and investigatethe origin of this oil. Since our meeting 1 have spoken with the platform and we have 600 bbls of slurried mud and cuttings and an additional 200 bbls of liquid mud now on deck to dispose of. We wouM like to continue disposal and monitor veryclosely any fluid coming from this annulus and obtain samples > > for analys~. > > We will let you and the commission know of any developments or > > changes. > > Wendy wouM you cc my home e-mail on any return correspondence. It is > > pdwhite~gci, net .Thanks. > > Paul D. White, Drilling Manager > > Forest Oil Corp. > > 907-868-2134 > > pdwhite~_forestoil, com 3> 2 of 3 7/26/01 11:36 AM RU//2 Annular disposal Subject: RU//2 Annular disposal Date: Tue, 3 Jul 2001 19:56:46 -0600 From: Paul White <PDWhite~forestoil.com> To: 'Wendy Mahan' <Wendy_Mahan~admin.state.ak.us> CC: Gary Carlson <GECarlson~forestoil.com>, Paul White <PDWhite~forestoil.com>, 'Osprey' <osprey2~gci.net> Dear Wendy, Thanks for meeting with Gary and myself to discuss the occurance of oil skim on the fluid from the RU #2 annulus. We reported that at 0300 hrs on 7/3/01 the 36" X 13 3/8" annulus wept a small ammount of fluid. (<2 1/2 gals.) The fluid has an unidentified oil sheen on it. We do not know the origin of this oil. In reporting this we are requesting that we continue to dispose of slurried mud and cuttings and obtaining samples of any fluids that appear in the annulus. We will send these samples to a lab on Thursday and investigate the origin of this oil. Since our meeting I have spoken with the platform and we have 600 bbls of slurried mud and cuttings and an additional 200 bbls of liquid mud now on deck to dispose of. We would like to continue disposal and monitor very closely any fluid coming from this annulus and obtain samples for analysis. We will let you and the commission know of any developments or changes. Wendy would you cc my home e-mail on any return correspondence. It is pdwhite~gci.net Thanks. Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2134 pdwhite~forestoil.com 1 ofl 7/26/01 11:35 AM ORES RATION June 22, 2001 Ms. Canuny Oechsli Taylor, Chair State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: RU #2 Annular Disposal Dear Commissioner Taylor, As of June 22, 2001, we have disposed of 43 batches of Class II fluid into the Redoubt Unit #2 annulus. This consists of 9,766 bbl of Class II slurry and 14,196 bbl of seawater, for a total volume of 23,962 bbl. We would like to continue to use this annulus for cuttings disposal. Therefore, we request a waiver to 20 AAC 25.080(d)(1) as it pertains to the 35,000 bbl maximum disposal volume in Redoubt Unit #2. Paul D. White Forest Oil Corporation Drilling Manager- Alaska Division FOR ES A T I 0 N June 22, 2001 Ms. Cammy Oechsli Taylor, Chair State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: RU #2 Annular Disposal Dear Commissioner Taylor, As of June 22, 2001, we have disposed of 43 batches of Class II fluid 'into the Redoubt Unit #2 annulus. This consists of 9,766 bbl of Class II slurry and 14,196 bbl of seawater, for a total volume of 23,962 bbl. We would like to continue to use this annulus for cuttings disposal. Therefore, we request a waiver to 20 AAC 25.080(d)(1) as it pertains to the 35,000 bbl maximum disposal volume in Redoubt Unit #2. Paul D. White Forest Oil Corporation Drilling Manager- Alaska Division ALASKA OIL AND GAS CONSERYA~ION CO~TISSION June 1,2001 TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-353g PHONE (907) 279-1433 FAX (907) 276-7542 Paul White Drilling Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Re: .Questions regarding Redoubt Unit Aquifer Exemption and Disposal Injection Order Applications Dear Mr. White: The Commission is currently reviewing the applications for Aquifer Exemption and Disposal Injection Orders submitted May 8, 2001. ARer consultation with EPA Region 10 and internal review, we have a few questions and comments. The injection intervals identified on the type log submitted did not correspond to the sands. Please resubmit the type log with the sand and proposed injection intervals more closely aligned, tabulating the net feet of sand per interval. Please also submit a SP log. You have requested thirteen sand intervals for consideration and propose to set a packer above the uppermost sand. It appears that the lowermost three sands are quite extensive and injection int° these three sand intervals would not require an aquifer exemption order. Please explain why you think you may need to inject into all thirteen sands intervals. If you plan to utilize the lowermost three sands initially, have you considered either installing the packer deeper or providing some other isolation mechanism. Since your platform operations will be zero discharge, the proposed disposal well will have to accommodate a significant mud and cuttings volume and is critical to your operations. Have you considered a backup plan in the event the disposal well fails? If so, please provide an explanation of any alternative disposal methods under consideration? If you have any questions regarding this request, please feel free to call Bob Crandall, Wendy Mahan or myself at the above phone number. TEM/jjc Sincerely, Thomas E. Maunder, PE Petroleum Engineer Notes on Observations of RU#2 Annular Please find attached the.requested charts and data series. In observing the flow back from the annular ball valve and drawing on past experiences with injections we would come to the following conclusion with a reasonable amount of certainty. The flow back is being caused by thermal expansion in the annular space. The slurry temperatures have been consistently 140 to 160 degrees F. With temperatures this high the fluid that is in adjacent annular will have an increase in temperatures. As any fluid does when heated there will be expansion. The fact that we have only seen a maximum of 7 gallons is one more factor to consider in making a judgement on the cause for this slight flowback. There is no pressure build up on the annular over time when this ball valve is closed. When opened there has been no observation of pressure build up. The one solid indicator that we do not have communication across the annular is noted in the last injection. Injection #26 was somewhat different from the last 25 injections. This injection had'a considerable mount of time between injection #25' and #26. 72 hours passed before a slurry of enough volume was ready for an injection. When .the in_iection was started it was noted that the pressure was very low as compared t~o..the prev. ious iniectiom. This prompted the. G&I team to shut down the injection to check ~-nd search for any possible leaks or wash outs in the pumping lines. After insuring that there were no leaks pumping continued. The well., was clearly on a vacuum a~er ~sitting for a lon~ ~eriod of time, this is indicated in the chart data. The slurry, coming in contact with formation brought the pump pressures back up to~eTevels that had been see in the past. With pump rates at 3 bpm the pressure built up and broke over as has been observed in past injections. The bleed off test as well indicates the integrity of the annular has not been broached. During the time that the injection unit was pumping without a build up of pressure water was observed weeping from the ball valve. With those observations noted above we have shut down operations tO make further observation and await interpretation of the data and observations being sent with this cover letter. If any further data may be required, I look forward to providing it promptly. Regards, Charles W. Alsobrook M-I IFE Engineer. Ce:Don Jones, Tony Tykalsky, Jesse H~ath 1400 1200 1000 8OO 6OO 400 200 Injection #26 on RU2 Annular Pump Pres BPM Time In I Sec. Intervals 3.5 2.5 0.5 Injection ltl5 on RU2 1200 1000 80O 600 400 200 Pump Pres ~BPM Time In I Sec. Intervals 2.5 2B 0.5 M-I Drilling Fluids. IFE Team Osprey Platform, Cook Inlet, AK. Well RU-2 Attn: Paul White, Don Jones. 5/21/2001 The data that you have requested is listed below in a graph that is broken down into three columns. Each of these columns is labeled with the samples that you requested be tested. The first sample was taken from the annulas bleed off valve. The second sample was water that was drawn from the SwacoDSR work area seawater pump. The third sample that was checked was the filtrate of the slurry that was batched up as Slurry #25. That slurry was pumped down RU#2 on the 20th of this month. J:~.;'~:':~-!ii'?:' 1.2 mill H2SO4 .75 mill H2SO4 .35 mill H2SO4 , -?!~¥..~:~¥. ;.. 2 ml/I H2SO4 1.2 mill H2SO4 1.15ml/I H2SO4 ;~i:!:!!';i~.'?::i? 200 ~ng/i 6(j"mg)l ' 4000 m'g/I ...... :¢'~.:,'!~:;:i:.~? 1400 mg/I 18000 mg/I 23000 mg/I ?:;:~!~::'i'i!¥.':ii:; 8.55 ppg. '8.6 ppg. '9.3 ppg. ,.., ::'~i?.?;:::,;~!i?:?;'"'" , 14 Ph ..... 7 Ph '10.5 P,h As can be clearly seen these are three very different samples. The Annular sample has a very high pH indicating that it has been in contact with green cement. The Pf is above a 1 ml/1 H2S04, which is indicative of cement contamination. The Seawater sample is perfectly normal for what would be expected in these waters. The slurry filtrate sample has one clear indicator that would be a very good marker to look for in any water that may weep from the annular bleed off valve. That marker is the Ca+ and the CL- tests. These two test show us that the slurry has a high concentration of CaCL in its chemical make-up. The CaC1- was used in the oil mud for salinity and oil mud activity, this is the only place in the well were this product is used and would not be present in any other slurries. If any fluid were broaching up to the higher annular these two Ions would be present in the similar concentrations as we see above. There would be some dilution of course that would result in a lowering of the concentration of Ca+ and CL- ions. However there would still be more than enough CaCL- to Identify the water as filtrate of the OBM slurry. My analysis of these tests is that the water weeping from the annular is drill- M-I Drilling Fluids. IFE Team Osprey Platform, Cook Inlet, AK. Well RU-2 ' water that has been in contact with cement. There is nothing to indicate that the fluid has been communicating with the injection annular. It will be my pleasure to answer further questions you have or provide any documentation that you may need. Regards, Bill Alsobrook M-I IFE Coordinator. Cc: Tony Tykalsky, Jesse Heath. NOTE TO FILE FOREST OIL CORPORATIO~I---PTD 200-165 On May 11, 2001 Forest provided documentation via fax of their cementing operations on the 9-5/8' x 13-3/8' disposal annulus and the 36' pile x 13-318' annulus on the subject well. These operations had been proposed by Forest about a week eadier following the observation of a "return flow" from the 36' pile x 13-3t8' annulus of RUg1 while conducting disposal operations in RU#2. No return flow was reported observed on RU#2. The intent of these operations was to eliminate any communication path(s) from the RU#1 wellbore to the surface as well as prohibit any communication between the RU~I and RLI~ wellbores. In accomplishing the cementing operation on the RU#1 disposal annulus, Forest pumped 50 bbls of seawater and 205 bbls of cement. They had intended to pump additional cement, but encountered some pump equipment problems while performing the operation. Given an annulus capacity of 106 bbls, they were successful in placing 99 bbls of cement slurry out of the 13-3/8' shoe. While perfoming the cementing operation, a "return floW' from the 36' pile x 13-3/8' annulus was observed after pumping the sea water and lead slurry (50 + 69 = 119 bbls). The flow rate was estimated at 8 gpm and continued while the tail slurry was being pumped. Total returned amount was 7.6 bbls of 13 pH seawater returns. Forest reported that the pumping pressures varied from 380-500 psi while pumping the seawater and lead slurry and were about 150 psi while pumping the tail slurry. Given the weight of the cement column, it is not unusual that the pressure declined while cementing. To avoid just pumping the cement away, an attempt was made to put the cement into the annulus using only the centrifical charging pumps on the unit but this was not successful. Problems were encountered getting the main cementing pump back on line and this time delay likely performed a "hesitatiorf squeeze on the cement in the wellbore. After pumping a total lead and tail volume of 205 bbls, the well locked up. 1000 psi pressure was placed on the annulus with no bleed off reported. After experiencing the lock up, the return flow ceased. Forest then proceeded to pump 42 bbls of cement slurry into the 38' pile x 13-3/8' annulus. Their pump rate was .6 bpm (25 gpm) with pump pressures starting at 325 psi and reaching 600 psi at the conclusion of the job. When ! discussed the operation with Rob Stinson and asked about the pressure behavior, he indicated they did not see any pressure decline while placing the cement. The disposal annulus on RU~2 was observed while pumping operations were conducted on RU#1. No pressure communication was observed. Based on the information reported by Forest, it is indicated that they successfully placed 99 bbls of cement outside the 13-3/8' casing shoe into the receiving formation. The vicinity of the 13-3/8' shoe has likely been sealed given the large volume of cement that was displaced from the shoe. Based on the observation of return flow, it is possible that some cement was placed in this flow path. It is not possible to say with certainty that the flow path was completely plugged by cement from the initial operations. Based on the reported pressures during the 36' pile x 13-3/8' operation, it appears that the cement was confined while being pumped. The pressure increased while pumping despite the increasing hydrostatic head from the cement. It is a most important observation that pumping pressures did not suddenly decline while the cementing operation proceeded. This is evidence that the cementing flow path was not breached during the course of the operation. In providing their report of the operation, Forest has requested for permission to resume annular disposal operations into RU#2. They have also requested that the seawater flush volumes be discounted when calculating the allowable 35,000 bbl permitted volume. It is my recommendation that Forest be allowed to resume disposal operations into RU#2, subject to the requirements previously approved. The only additional requirement I would recommend is that their disposal pumping rate be limited to 3 bpm. This should not present any difficulty since nearly all of the data provided to date has at most been slightly over 3 bpm. With regard to the request to discount the seawater volume, I believe this request is premature at this time. As operations proceed and the total volume approaches about 30,000 bbls ~ t-~-V,,~%~,- ~-~- ,.~ ~,.~-~-.¢~ ~ o,~ ~-~~.~-~, Injection #26 on RU2 Annular 1400 1200 1000 8O0 6O0 400 200 · Pump Pres BPM Time In I Sec.. Intervals 3.5 2.5 .1.5 1 0.5 Injection #15 on RU2 1200 1000 800 600 4OO 2O0 0 Pump Pres ..... BPM Time In I Sec. Intervals 2.5 1.5 0.5 B P M Annular Disposal Approval--RU#2 Subject: Date: From: To: CC: Annular Disposal Approval--RU#2 Fri, 18 May 2001 11:55:30 -0700 Tom Maunder <tom_maunder@admin.state.ak.us> Paul White <pdwhite~forestoil.com>, Rob Stinson <RDStinson~forestoil.com> Daniel T Seamount JR <dan_seamount~admin.state.ak.us>, Julie Heusser <julie_heusser~admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli~admin.state.ak.us>, John D Hartz <jack_hartz~admin.state.ak.us>, Bob Crandall <bob_crandall~admin.state.ak.us>, Steve Davies <steve_davies~admin.state.ak.us>, Wendy Mahan <wendy_mahan~admin.state.ak.us> Paul and Bob, Thank you for bringing the information regarding the injectivity test conducted last evening (5/17/01) on RU#2. Based on the recently completed cementing operations on Rug 1 and the injectivity test information, Forest Oil Corporation is authorized to resume annular disposal operations into the 9-5/8" x 13-3/8" annulus of RU#2. This approval is subject to the conditions of the earlier approvals for disposal operations into RU#2. Please continue the excellent monitoring program that is in place. Do not hesitate to call immediately should anything unusual be observed with either RU#1 or RU#2. Good luck with your operations. Tom Maunder, PE Petroleum Engineer AOGCC Tom Maunder <tom maunder(2~).admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 1 7/26/01 11:35 AM RU#1 Subject: Date: From: To: RU#1 Fri, 11 May 2001 17:04:56 -0700 Tom Maunder <tom_maunder~admin.state.ak.us> Julie Heusser <julie_heusser@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount~admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, John D Hartz <jack_hartz~admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Wendy Mahan <wendy mahan~admin.state.ak.us> All, I received a fax, which I have passed to Julie, from Rob Stinson today reporting on their cementing activity on the annuli of RU#1. Last night they pumped a total of 205 bbls of cement into the 9-5/8" x 13-3/8" annulus. With a capacity of 106 bbls, this means they got 99 bbls or so out of the shoe. They had intended more, but had some pump difficulties which by default performed a hesitation squeeze of the intervals below the shoe. They ultimately held 1000 psi surface pressure against the cement. After cleaning out the lines, the Drilling Supervisor reported that he could visually see cement standing inside the annulus. During the operation there were fluid returns out of the pile x 36" annulus. The reported flow rate was about 8 gpm. Flow started about the time the tail slurry was started and continued essentially at a constant rate until the cement locked up. To complete the operation they pumped some 45 bbl of slurry down the pile x 13-38" annulus. They report an increasing pressure while pumping. I think this information is important. It would indicate that they were filling some space throughout the pumping even with the increasing head of the cement column. The one response we would not want to see would be a pressure increase followed by a sudden drop. That would indicate that something has broken down. In the submitted report, Forest makes 2 requests. They ask that the seawater so far pumped into the disposal annulus not be counted against the 35000 bbl total and they request to resume disposal into RU#2. I indicated to Rob that I would pass this information on to the , Commissioners, however I did not expect that a decision would be made today. Tom ! of 2 7/26/01 11:35 AM · FUI, Lm~5'I' U 1J., ALASI~. FOREST OI'L CORPORATION 310'K Street~ Suite 700 Anchorage~ Alaska 99501 (907) 258...8600 - Office (907) 258-8601 - Fax TO: FAX NUMBER: DATE: FROM: PHONE NUMBER: TIME: Total Number of Pages Including Cover Sheet: COMMENTS: / yo.."- ¢"// L~. uu1 · {' P'UI~'I' UIL ALASKA -E S T O i L C 0 R P 0 R A T ! 0 c?.~,./,,,../.~,~,%F,,' o...r,:/?,.,.~/-,..~,~.yO./ ~ uuz N May ll,2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7~ Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: RU #2 Annular Disposal Dear Mr, Maunder, We performed the previously approved abandonment of both annuli on Redoubt Unit # 1 last night. The details are outlined below. As we discussed in our meeting on May 8, we believe the flow on RU #1 was simply a pressure response to the annular disposal operation on RU#2. At this time, we request to resume the annular disposal operation on RU #2, notifying AOGCC of any abnormalities if they are encountered. We will continue to closely monitor RU#I for any problems. Due to the successful nature of the RU #1 annular abandonment, we believe that an injectivity test into RU #2 will not be necessary. Commencing disposal operations on RU #2 will show any behavior that would be encountered in an injectivity test. As of May 5, there had been 3,828 bbls of Class II slurry and 8,365 bbls of seawater injected into RU #2. We request that the seawater volumes used for pre-flush and post- flush be excluded from the 35,000 bbl limit set in 20 AAC 25.080(d)(1) as it pertains to this well. Abandonment: 1.) Pre-flushed RU #1 - 9 5/8" x 13 3/8" annulus with 50 bbls seawater ~ 3bpm. 2.) Pumped 200 sx (69 bbl) of 12,5 ppg cement in RU #1 - 9 5/8" x 13 3/8" annulus ~ 3 bpm 3.) Pumped 660 sx (136 bbl) of 15.8 ppgCement in RU #1 - 9 5/8" x 13 3/8" annulus ~ 3 bpm. Locked up at this volume of slurry away, Received 7.6 bbl of 13 pH seawater returns in the 13 3/8" x 36" annulus while pumping this cement slurry. 05/11/01 FRI 12:08 FAX 907 258 8601 FOREST OIL ALASKA 4.) Pumped 200 sx (42 bbl) 15.6 ppg cement into RU #1 - 13 3/8" x 36" annulus at 0.6 bpm. Pressure varied from 325 psi to 600 psi. Note: No pressure response observed in RU #2. Sincerely; Forest Oil Corporation Drilling Engineer Cc: Paul While, Forest Oil Drilling Manager- Alaska Division Re: RU #1 Annular Abandonment Subject: Re: RU #1 Annular Abandonment Date: Tue, 08 May 2001 17:00:30 -0700 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: Rob Stinson <RDStinson~forestoil.com> CC: Gary Carlson <GECarlson~forestoil.com>, Daniel T Seamount JR <dan_seamount~admin.state.ak.us>, Julie Heusser <julie_heusser~admin.state.ak.us>, John D Hartz <jack_hartz@admin.state.ak.us>, Bob Crandall <bob_crandall~admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Wendy Mahan <wendy_mahan~admin.state.ak.us> Rob, Thanks to you and Gary for meeting with us to discuss your proposal. It was the concurrence of the Commission staff members present that your plan is prudent. The only addition I would recommend is that once the cement is in place in the disposal annulus, you monitor any cement fall by using the displacement tanks on the cementing unit to keep the annulus fluid filled until it stands full. By copy of this email, you have approval to proceed. Good luck. Please contact me at any time with any questions. Tom Maunder, PE Petroleum Engineer AOGCC Rob Stinson wrote: Tom, As per our discussions today, Forest Oil proposes to perform the following abandonment of the annuli on our Redoubt Unit #1 well: 1) Pump 50 bbls of seawater into 9 5/8" x 13 3/8" annulus at 3 bpm. 2) Pump 200 sacks of 12.5 ppg lead cement slurry in 9 5/8"x 13 3/8" annulus at 3 bpm. 3) Pump 1500 sacks of 15.8 ppg tail cement slurry in 9 5/8" x 13 3/8" annulus at 3 bpm. 4) Pump 200 sacks of 15.6 ppg cement slurry in 13 3/8" x 36" annulus at no more than 1 bpm. Any fluid returns at surface during these cement jobs will be captured. Also, all annuli will be monitored during this procedure. We possibly will see a pressure response on the R U #2 annulus. If this occurs, we will monitor the pressure, as it should return back to 0 psi once the cement has set up. We wouM like permission to proceed with this outlined abandonment. > Rob Stinson 1 of 2 7/26/01 11:35 AM 05/08/01 TIJE 08;34 FAX 907 258 8601 FOREST OIL ALASKA FOREST OIL CORPORATION 310'K Street~ Suite 700 Anchorage, Alaska 99501 (907) 258-8600 - Office (9o7) 2ss-86oz - Fax TO: FAX NUMBER: DATE: FROM: PHONE NUMBER: TIME: Total Number of Pages Including Cover Sheet: COMMENTS: /o~ / RECEIVED 'HA'( 0, 8 2001 Anchorage' , i I~ool 05/08/01 TI. rE 08:35 FAX 907 258 8601 FOREST FOREST OIL ALASKA O i l- CO r Po RAT i "'~" ~" · .c.~;~.'/~ .~o..zr~ o~.. ¢-',.~,e..~/ · . ~..c~,c/,.o,~,.~.,~.7,,' ~c .~,~ ..~..9.:;'t~./ O02 O N May 8, 2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7m Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: RU #2 Annular Disposal Shutdown Dear Mr. Maunder, ' Forest Oil has ceased all a,nnular disposal on 'the OsPreY Platform, as of 5:30 AM on May 6, 2001. This was due' to a breakthrough into RU #1 during injection batch #29. Injection ~29 started at 1:50 AM on May 6 and stopped at 4:37 AM. At 4:03 AM, with 217 bbls of slurry and 165 bbl ofpostflush aWay, saltwater with a PH of 13, chlorides of 9200 and a light sheen of oil started to leak from the outer annulus on RU.#1. The flow stopped at 9:30 AM 'with a total volume of fluid returned to surface of 8 ½ bbl. The pressure graph of injection ~29 is attached. Sincerely, Forest Oil Corporation Drilling Engineer Attachment: Oraph of Injection' #29 HAY 0 8 2001 Cc: Paul While, Forest Oil, Drilling Manager .RECEIVED RU#2 INJECTION ~29 5/06/2001 HAY 0 8 2001 Alaska Oil & Gas Cons. Anchorage 1400 -, 1200 1000 8OO 6O(} 400 -- 200 [ · . . · ..'.......' . . ......'......, . .'.- _ . . - : '.:..... .. · .~ ..:'-'.- ; .....',.. ..... '~.?.'..'..'..-.:.:.. '='.'..,-. :.'.-:.-..;f.;.~..~...j'...:j,-,..:. ..:.:.-.': i.'..."::--.:: ~. "."':"- .':.'.:;::".,-.. ;,:. '..'.. 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'...... -: .' ~ ]. :.'.'" '.';%.:, . .' ..'.j~ · -. :: .._.....:-..' . .-.. · ._. -.- ......;.. .... .... · . · · ... . . ... . · , . - ... · ...~ .. ; ...... .' -' -~ -' : '.":' ,..:- -..-....~ -.. ,,:;.,;:.. · -.-....- . '.~.-.'.. · .., .. · - ' .' '..' ~ " . .~..~,...; ........:.-. : --..'.-..-. ......'....'~.. '~:.. ...% ,'.' -,:,= -, .' ~- ;, .,,,,.~ .' ' ' · -.' . .' ' . .' '-'~". .'..-',:. · - .. Annular Disposal RU#2 Subject: Date: From: To: CC: Annular Disposal RU#2 Thu, 03 May 2001 16:08:59 -0700 Tom Maunder <tom_maunder@admin.state.ak.us> Paul White <pdwhite@forestoil.com>, Rob Stinson <RDStinson~forestoil.com> Julie Heusser <julie_heusser@admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Wendy Mahan <wendy_mahan@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount~admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us> Paul and Rob, Thank you for coming over with the temperature log presentation. Thanks to Art as well for overlaying the two passes. That makes interpretation much easier. As discussed in the meeting, the temperature response following pumping indicates that the disposed fluid is entering a sandstone approximately 70' md below the 13-3/8" shoe. No evidence was presented that would indicate there was any fluid movement above that depth. By copy of this email, Forest Oil Corporation is authorized to resume annular disposal into RU #2. Continued disposal operations must comply with the decisions issued previously regarding this well. As disposal operations continue, we look forward to ongoing discussions regarding the information you will develop. Please contact me with any questions. Tom Maunder, PE Petroleum Engineer AOGCC Tom Maunder <tom_.maunder¢~admin.state.ak.us> :i Petroleum Engineer ,t Alaska Oil and Gas Conservation Commission ii 1 of 1 7/26/01 11:34 AM 03/02/2002 13' $1 FAX 907 258 8601 FOREST 0IL ALASKA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: __ Alter casing: Repair well: Change approved program: Puil tubing: Name of Operator Forest Oil Corporation 3. Address 310 K Street, Suite 700 Anchorage, Alaska 99{i01 Operation shutdown: Re-enter suspended well: Plugging: "---Time extension: ~ Stlmul~-te: Variance; Perforate; Other. X (Drill Stem Testing) .... 5. Type ofwell; 6, Datum elevation (DF or KB) Development: 90' MSL .. Exploratory: X 7, Unit or Property name Stratlgraphic: Redoubt Unit Service: -4. Location of well at surface 1910' FSL, 314' FEL, Sec, 14, T07N, R14W, SM At top of productive interval 8:22' FNL. 39' FEL, Sec. 25, T07N, R13W, SM At effectfve depth At total depth 1439' FNL, 249' FWL, Sec. 25, T07N, R13W, SM 12. Present well condition summary · T,ntel.depth; measured true vertical 20,203'. 13,142' 8. Well nunlber Redoubt Unit 9. Permit number 201-031 10, APl number `60-733-20501-00 11. Field/Po01 , Redoubt Shoal Field Plu~ls (measured) Effective depth: measured 20,056' true vertical 13,040' Junk (measured) Casing Length , Size Cemented Measured depth Structural NIA N/A N/A N/A Conductor 200' 30" Driven 200' Sudace 3,530' 13 3/8" 6462 cuft 3,530' Intem~ediate 10,5t 7' 9 5/8" 4613 CU f~ 10,517' Drilling Liner 8,722' 7 ~/8" ;258 cuff 18,416' Production Llner 1,896' .6 1/2" 806 cuff 20,143' Perforation depth: measured True vertical 2,918' 7,114' 'i '1,960' 1 "~,101' true vertical Tubing (si=e, grade, and measure~l depth) 3 1/2" 9.34¢ L-80 ~ 18,065' MD Packers and SSSV (type and measured depth) 13, Attachements Descrlption summary of proposal; X. _ Detailed operations program: BOP ske!ch: ._X_ .... 14. Estimated date for commencing operation I 15. Status of wall classification as; 03-May-02 16. if proposal well verbally approved: Oil: X Gas; _ Suspended: ...... Name of approver Date approved Sen/ice: 17. ] hereby certify that the foregoing is true and correct to the best of my knowledge. Signed'..._~" Title: Drilling Engineer Forest Oil Corporation Date:~.~_~!/~.~,. Conditions Of approval: Notify Com.lssion so represe,~tative may witness ,,~O~~ _~'~' '~'~~~,~_'_~'¢'[%.,..-r~. J [~'~p'~ '~ :, ____ ' Lo~tion clearande Plug integri~ BOP Test..~ Approved by order of the Commissioner Form 10-403 Rev 06/15188 fSngmal Signed By Cammy Oechsli Taylor MAY 0 g 'ZOOZ SUBMIT ~N TP, IPLIC^T'E 05/o2/2002 13'51 FAX 907 258 8601 FOREST OIL ALASKA {' FOREST OIL CORPORATION Redoubt Shoal Fi~.ld - Osprey Platform Redoubt Uni! #4 Drill Stem Tests 1. Nipple down production tree. 2. Nipple up 13 51§" 5M BOPE and test. 3. POH wi 3 ~" tubing, laydown all and send to beach. P/U all 5" and 4" drillpipe necessary for all of the testing. 5. Rig up Surface Test Equipment and Nitrogen Equipment. Ddll Stem Test Lower Gas Sands (9,195'- 9,220' MD and 9,348' - 9,400' MD) , 7. Set Bridge Plug at 6,200' 8. Drill Stem Test Upper Gas Sands (5,850' - 6,015' MD) 9. RIH to bridge plug. Viscosify KCI and drill out bridge plug_ 10. Polish 7 5/8" liner top with polish mill. 11. Run and cement 7 5/8" tieback to cover perforations from DST//1 and DST/f2. New liner top will be approximately 5,700'~-~ 12. Clean out 9 5t8" to new 7 5/8" liner top and test casing to 3,000 psi. 13. Clean out 7 5/8" to 5 ~" liner top. 14. Clean out 5 ~" to 20,056' (landing collar). Displace out viscosified KCI with fresh KCI and filll:er before POH. 15. Perform Hemlock DSTs in two tests. The first set of peris (19,220'- 19,270', 19,400'. 19,43(7, 19,625' - 19,775')~ shot wit~-pmssure actuated guns. The second test will open up an additional set of parrs (19,020'- 19,100') for a commingled DS']'. 16. Rig down Surface Test Equipment. 17. POH with test assembly, laying down exce.~ drillpipe. 18, RIH wi 3 %" tubing. 19. Nipple down BOPE. 20. Nipple up production tree and test. . 05/02/02 Fage 1 of 1 05/02/2002 13:$1 FAX 907 258 8601 FOR FOREST OIL ALASKA E S T O i L C O R P O R A T I 0 N May 2, 2002 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Sui[e 100 Anchorage, Alaska 99§01 Attn: Mr. Tom Maunder Re: Redoubt Unit ~4 - Re-entry for DSTs Mr. Maunder, Forest Oil requests to re-enter Redoubt Unit ¢f4 in order to.further evaluate the_,qr¥onek .Gas sands that were logged, as well as evaluate the' Hemlock oil, sands .on the'~l Flank of the Redoubt Shoal field, These will be conventional Drill. Stem Tests, performed,, with drill pipe as a workstring. The perforations for the gas sands will'be covered up after the testing with a cemented 7 5/8" tieback. Attached are the 10-403, operations outline and' BOP schematic, If there are any questions, please contact me at 907-258~8600. Robert Stinson Drilling Engineer-Alaska Division Forest Oil Corporation \V~NCFL$1~ANC_Orilling~edoulat U nit ~4\Testing~RU #4 Te. sting 403.doc RECEIVED MAY 0 2 ZOOZ Alaska0il&6a~60~.~ A.d~ora~ Date Modified: 5f2./02 Date F~rep~rJ: 5121'~)~ 05/02/2002 13'$1 FAX 907 258 8601 , FOREST OIL ALASKA OO7 Nabors Rig 429 13-5/8" 5000 psi BOP Stack Redoubt Unit #4 ........... 5000 psi Annular I ! 5000 psi Blind Rams 5000 psi Pipe Rams 3" Kill Line 1 = HCR Valve 2 = Gate Valve Mud Cross 5000 psi Pipe Rams 3" Choke Line 13 5/8" 5M Wellhead 13-3/8" Surlhce Casing 9-5/tt" lnlennedlule ~ -' [ TRaNSaCTION REPORT RAY-03-04 FRI 10:07 all ~ ~ N~ DP ~ ~ DRTE STRRT REOEIVER TX TIRE PAGES TYPE NOTE _______ ~ x RgY-03 10:05 ~R 2588601 1'54" 7 SEND OK , ALASKA OIL & GAS CONSERVATION COMMISSION 333 W. 7TH AVE, SUITE 100 ANCHORAGE, AK 99501-3539 FACSIMILE TRANSMITTAL SHEET TO: FROM: FAX NUMBER: DATE: TOTAL NO. OF PAGES INCLUDING COVER: PHONE NUMBER: SENDER'S REFERENCE NUMBER: YOUR REFERENCE NUMBEPc [] URGENT [] FOR REVIEW [] PLEASE COMMENT [] PLEASE REPLY [] PLEASE RECYCLE NOTES/COMMENTS: PHONE NO. (907) 279-1433 FAX NO. (907) 276-7542 RU #2 Annular Disposal Subject: RU #2 Annular Disposal Date: Tue, 24 Apr 2001 08:28:56 -0800 From: Julie Heusser <julie_heusser~admin.state.ak.us> To: Tom Maunder <tom_maunder~admin.state.ak.us>, Wendy Mahan <wendy_mahan@admin.state.ak.us> Good Morning Wendy and Tom, Thanks for meeting with Forest re the annular disposal on Redoubt Unit #2. Tom, I like your idea of asking for additional information. What do you think about asking them to present a selection of pressure data all on the same scale and possibly even on the same page. What we would be looking for is an evaluation of injection pressure trends over time to help determine if we have a problem developing? For example, Forest might choose pressure data from the initial one or two AD events, and then selected events over time including the ones (2 or 3?) before AD was shut-in. Thanks Julie I of I 7/26/01 11:34 AM Annular Disposal RU #2 Subject: Date: From: To: CC: Annular Disposal RU #2 Fri, 20 Apr 2001 14:55:05 -0700 Tom Maunder <tom_rnaunder~admin.state.ak.us> Paul White <pdwhite~forestoil.com>, rob, stinson Julie Heusser <julie_heusser@admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount~admin.state.ak.us>, Wendy Mahan <wendy_rnahan@admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, John D Hartz <jack_hartz~admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us> Rob, This message acknowledges your call at about 1345 regarding the "seepage" you have recently noted when the 3" valve on the 36" pile of RU #2 was opened. Copied below are the notes I took during the call of about an hour ago. "Call from Rob Stinson...he received a call from the rig...got 3" outlet valve on 36" pile and open ports...fluted hanger...normally keep valve closed...opened valve and got a gallon of fresh water out...usually wash down well room...stopped the practice, however they have been doing operations that result in getting water from above...the other day they opened the valve again...did 20 bbls sea water preflush and after disposing 140 bbls of slurry they noticed a "seepage" out of the valve that amounted to 3 gallons in 30 minutes and then it stopped...did not stop disposing batch...took it upstairs and analyzed...fresh water with high ph...what are current disposal totals...will have to get...this was batch 26...asked Rob to get the pressure plots for this batch and say #15 to compare...presently coring so not generating much in the way of cuttings...handling wash water that had been shipped ashore...told him I would inform the Commissioners and get back to him" I have appraised the Commissioners of your report. We appreciate your prompt attention to this matter. The Commissioners asked me to send you the following: As of 1450, April 20, 2001 you are directed to cease annular disposal into RU #2 until you have presented an analysis of the information you have available regarding operations up to and including batch #26 and the Commission has had an opportunity to review same. We look forward to arranging a mutually convenient time next week to discuss this matter. Please contact me regarding setting up a meeting. Tom Maunder, PE Petroleum Engineer AOGCC Tom Maunder <tom_maunder~admin. state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 2 7/26/01 11:34 AM Annular Disposal Approval--RU#2 Subject: Annular Disposal Approval--RU#2 Date: Mon, 02 Apr 2001 15:08:24 -0700 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: Paul White <pdwhite@forestoil.com>, Rob Stinson <RDStinson@forestoil.com> CC: Julie Heusser <julie_heusser~admin.state.ak.us>, John D Hartz <jack_hartz~admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, Wendy Mahan <wendy mahan~admin, state.ak.us> Paul and Rob, Thank you for meeting with us to relate the current status of annular disposal operations on RU#2. We do appreciate the difficulties you are encountering while honoring the EMW gradient determined with the drillout leakoff test. By copy of this email, we are authorizing you to investigate the effects of increasing your batch size to about 250 bbls and disposing at up to 18.0 ppg EMW at the 13-3/8" shoe. At this time, please keep the slurry weight at 10 ppg. In order to allow further consideration of the information you may develop, we suggest that a meeting be scheduled at 1330 Thursday to look at the new disposal information. Please contact me with any questions. Tom Maunder, PE Petroleum Engineer AOGCC Tom Maunder <tom maunder¢~admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I of I 7/26/01 11:34 AM This is it FW: 3-26-2001 SWACO/DSR INJECTION DATA]] % i. Subject: This is it FW: 3-26.2001 SWACOIDSR INJECTION DATA]] Date: Mon, 02 Apr 2001 11:06:24 -0700 From: Tom Maunder <tom_rnaunder@admin.state.ak.us> To: Julie Heusser <julie_heusser@admin.state.ak.us> Here is that document. Subject: Re: [Fwd: FW: 3-26-2001 SWACOIDSR INJECTION DATA] Date: Wed, 28 Mar 2001 10:41:19 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Rob Stinson <RDStinson@forestoil.com>, Paul White <pdwhite@forestoil.com> CC: Bob Crandall <bob..crandall@admin.state.ak.us>, Julie Heusser <julie_heusser@admin.state.ak.us> Rob and Paul, Paul forwarded this information on disposal #3 into RU#2 to me Monday morning. While looking at it, I called Rob and forwarded a copy to him. We discussed that in examining the 3rd sheet (pressure calculations) of the workbook, it appears that the depths shown with the diagram are for the RU#i and RU~2 rather than just for RU~2. In looking at the formulae used, I first thought the safety factor might not have been applied to the calculations beginning in E23. I have had an opportunity to further examine the pressure calculation sheet. I have not checked every calculation or notation, but I do haVe the following comments. 1--With regard to the calculations beginning in E23, the pressure safety factor is not applied here, but does appear to be applied in the calculations beginning in I48. 2--Referencing the drawing and the volumes shown there, I am uncertain where and how these were determined or what the diagram is attempting to illustrate. As noted above, I pointed out that the 2 depth numbers listed are for RU~I and RU#2 not just for RU~2 as would seem appropriate. These depths are also the TVD depths, not MD depths. The TVD for the 13-3/8" shoe in RU~2 appears to have been used for the pressure calculations in the sheet which is appropriate. It does not appear that the MD values have been used to calculate the volumes. The 2 smaller volume numbers with the diagram are the product of the depths listed in cells G23 and G24 and the volume factor .0838 bbl/ft. The remaining volume figure is the sum of the others. The .0838 bbl/ft is not the volume factor for the 9-5/8" x 13-3/8" annulus. According to my Halliburton book, .0581 bbl/ft is the factor for 9-5/8" inside 13-3/8" 72~. It appears appropriate that all information and calculations contained on this spreadsheet be verified and the correct document forwarded to the platform. I would suggest that such document be created/edited in the Forest Office, some visible document control I of 3 4/2/01 12:2t PI~ This is it FW: 3-26-2001 SWACO/DSR INJECTION DATA]] ,. notation be added, appropriate cells password protected and the document be sent to the platform for use. I would appreciate a confirming note when the excel document has been checked, verified and dispatched. 3--I would appreciate an explanation of your actual procedure. From the notes below the pressure chart, it appears you are preparing 100 bbls of 10.0 ppg slurry. Beyond that I cannot tell if that 100 bbls is mixed with some 400 bbls of seawater and pumped or if the 100 bbls is cut with 100 bbls of seawater and the mixture pumped as a pill. 4--Further elaboration/explanation of the perceived/determined limitations you are experiencing while conducting annular disposal in RU#2. As communicated previously, the controlling factor with regard to annular disposal in RU#2 is the pressure response as determined when the drillout leakoff test was conducted. The determined bottomhole EMW of 15.5, protected by a 100 psi (.7 ppg EMW) safety factor cannot be exceeded while conducting your disposal operations. This is specifically noted at 20 AAC 25.080 (e) (2). We encourage open dialogue with regard to this operation and will entertain such proposals as you may wish to submit requesting modification(s) to the present approval. Sound engineering judgment and the regulations at 25.080 will guide any decision. Please contact me with any questions. Tom Maunder, PE Petroleum Engineer AOGCC Tom Maunder wrote: Subject: FW: 3-26-2001 SWACO/DSR INJECTION DATA Date: Mon, 26 Mar 2001 13:26:38 -0700 From: Paul White <PDWhite6forestoil.com> To: 'Tom Maunder' <tom maunder~admin.state.ak.us> > ..... Original Message ..... > From: OSPREY PLATFORM [SMTP:osprey2@gci.net] > Sent: Monday, March 26, 2001 11:25 AM > To: Paul White > Subject: 3-26-2001 SWACO/DSR INJECTION DATA > > <<Injection #3 on 25th.xls>> - > Name: Injection #3 on 25th.xls > Injection #3 on 25th.xls Type: Microsoft Excel Worksheet ( app l i ca t i o n / vnd . ms-excel) > Encoding: base64 > > 2 of 3 4/2/01 12:21 PM This is it FW: 3-26-2001 SWACO/DSR INJECTION DATA]] > Tom Maunder <tom maunderOadmin.state.ak.us> > Petroleum Engineer > Alaska Oil and Gas > > Tom Ma under > Petroleum Engineer > Alaska Oil and Gas > 3001 Porcupine Dr. > Anchorage > AK > 99501 > USA > Additional Information: > Last Name Maunder > First Name Tom > Version 2.1 Conservation Commission Conservation Commission <tom maunder~admin.state.ak.us> -- Fax: 907 276-7542 Work: 907 793-1250 Conference Software Address Tom Maunder <tom maunder~admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Maunder <tom maunder~admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 3 of 3 4/2/01 12:21 PM 15:15 Fb.~ 907 ZS~ ~601 FOREST OIL ALASKA FOREST OiL CORPORATZON 31OK Street, Suite 700 Anchorage, Alaska 99501 (907) 258-86oo - Office (907) 258-8601 - Fax TO: FAX NUMBER: DATE: FROM: PHONE NUMBER: TIME: Total Number of Pages Including Cover Sheet: COMMENTS: Id_Juu1 RU #1 9 518" x t3 3/8" ANNULUS DIAGNOsIs 03122/01 T~,~E RECEIVED MAR, ZOO March 20, 2001 Alaska Oil & Gas Cons. Commissi~ Anchorage From: Paul White, Drilling Manager To: Forest Oil Corporation, Drilling Foremen and operating personnel Osprey Platform Redoubt Unit #2 OBM Drill Cutting Fluids Disposal/Annular Disposal Procedure OBM drilled cuttings and fluids generated during drilling operations on the Osprey Platform will be disposed of by annular disposal. A designated annulus will be selected and all annular disposal will be performed using the following guidelines. All personnel involved with the daily operations of grinding and disposal will adhere to FOREST OIL CORPORATION/Drilling Osprey Platform HSE procedures. Each individual will be required to review and understand Annular Disposal/OBM Handling process. Training will be provided onsite prior to operating equipment. Annular disposal is regulated by the AOGCC under 20 AAC 25.080 'ANNULAR DISPOSAL OF DRILLING WASTE'. A copy of the approved permit will be on site prior to any disposing. Insure that all annular disposal is being done on an approval annulus. All piping and valves, from G&I process to the well head annulus valve, will be pressure tested to 2500 psi, prior to beginning operations. All pressure testing will be witnessed by the FOREST OIL Drilling Foreman on site and recorded on a test chart. Perform injectivity test on approved annulus with water prior to initial slurry disposal. With FOREST OIL CORPORATION Drilling Foreman present, begin injection. See attached pressure schedule for maximum injection pressure. (Maximum pressure is based on maximum EMW of 15.5 at casing shoe 2934' TVD, with 100 psi safety margin) Establish disposal rate and hold for ten minutes. Chart and record injectivity test. All cuttings and fluids to be disposed of will be received frOm the drill rig shakerS/surge tank via the vacuum system to the cuttings reduction tank for processing. Cuttings will be processed across shakers dressed with screens to allow separation of material to grinder mill. Classifier for particle size will be 50 mesh. Cuttings that go across shakers will be run through the regrind tank until acceptable particle size is achieved. Sized cuttings will be stored in the disposal tank. Have the Mud Engineer perform a rheology check prior to pumping slurry. Annular Disposal Procedure Page 2 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage A 20 bbl water preflush will be pumped down the designated annulus to establish disposal rate parameters, followed by volume of available slurry of OBM cuttings from the disposal tank at not greater than a 11.7 ppg density with a viscosity of 50 sec. This will be followed by a 260 bbl water flush to clear the annulus volume to the casing shoe depth plus 50% excess. See attached pressure schedule for maximum injection pressure. (Maximum pressure is based on maximum EMW of 15.5 at casing shoe 2934' TVD, with 100 psi safety margin) Monitor disposal pressure closely for indication of a gradual annulus packoff. After completing annular disposal shut-in annulus, do not bleed off annulus pressure. Bleed off pressure on disposal line, Depending on weather conditions, it may require that all lines and surface equipment be freeze protected. A daily log will be filled out after each disposal, note on log any abnormalities during disposal. Notify the Drilling Foreman during disposal. A gauge will be installed on the RU#1- 9 5/8" X 13 3/8" annulus. This annulus and the 13 3/8" X 36" conductor annulus shall be monitored during all disposal operations. In the event there is an~' pressure on _the gauge or an}' fluid returns from the 13 3/8" X 36" conductor annulus immediate~j cease injection and report to Forest Oil Corporation drilling foreman. Redoubt Unit #2 Annulus Maximum Injection Pressure Slurry Density (ppg) 8.4 8.5 8.6 Maximum Injection Pressure (psi) 976 961 946 8.7 931 8.8 915 8.9 900 9.0 885 9.1 870 9.2 RE( 9.3 .',E!VED 854 839 9.4 MAI 2 g zOo1 824 9.5 Alaska Oi! & ( 9.6 ~ 809 as Cons. Comm!ss!o~ '~chorage 793 9.7 778 9.8 763 9.9 748 10.0 732 10.1 717 10.2 702 10.3 687 10.4 671 10.5 656 10,6 641 10.7 626 10.8 610 10.9 595 11.0 580 11.1 564 11.2 549 11.3 534 11.4 519 11.5 5O3 11.6 488 11.7 473 Re: RU 2 Annular Disposal Area Subject: Re: RU 2 Annular Disposal Area Date: Wed, 21 Mar 2001 17:34:32 -0900 From: Julie Heusser <julie_heusser(~admin.state.ak.us> To: Robert Crandall <Bob_Crandali@admin.state.ak.us> CC: "Hartz, John" <jack_hartz@adm in.state.ak, us>, "Maunder, Thomas" <tom_maunder@admin.state.ak.us> Hi Bob, Great response!. In summary, it sounds as if you would be supportive of approval of RU 92 if we were to specify monitoring of the RU #1 annuli during any annula, r disposal operations on RU 92. ~ ~ ~ ~~ 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. Do you have any comments? RPC I of 1 3/21/01 5:34 PM Re: RU 2 Annular Disposal Area Subject: Re: RU 2 Annular Disposal Area Date: Wed, 21 Mar 2001 17:36:52 -0900 From: Julie Heusser <julie_heusser@admin.state.ak. us> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: Robert Crandall <Bob_Crandall@admin.state.ak.us>, "Hartz, John" <jack_hartz@admin.state.ak.us> Tom, it appears that you are supportive of approval of RU%2 annular disposal operations. Sounds good to me. Julie Tom Maunder wrote: Bob, Thanks very much. >From an operations point of view, the construction of the well has gone very well. AOGCC field Inspectors witnessed the surface casing cementing operation, surface casing pressure test, initial leakoff and the pump in test. In their reports, the Inspectors indicated that no problems were experienced with any of the operations. The key observations of each operation were: 1)--lst stage cement was raised to above the stage collar at 2000' md. 2)--2nd stage cement was circulated to surface. 3)--The surface casing was tested to 3000 psi with no observed loss. 4)--After drilling 20' of new hole, the open hole was tested to leakoff at 1/2 bpm. Fluid was injected into the exposed formation at a gradient of .81 psi/ft. 5)--After setting and cementing the 9-5/8" casing, a pump in test was conducted down the 9-5/8" x 13-3/8" annulus at 1/2 bpm. Fluid was injected into the exposed open hole at a gradient of .69 psi/ft. Based on the available mechanical information it is indicated that the RU #2 wellbore has been satisfactorily isolated within the earth and that fluids injected at gradients less than .81 should enter formations at depths below the shoe. i agree with your recommendation that the 13-3/8" x 9-5/8" annulus of RU #1 be monitored for any indications of communication with RU #2. To reduce the likelihood of establishing any communication path the pressure gradient at the 13-3/8" shoe of RU #2 must not exceed .81 psi/ft. A prudent operator would conduct any disposal operations employing a safety factor to assure that the .81 psi/ft gradient is never exceeded. Julie, please let me know if you need anything further. Tom 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 1 of 2 3/21/01 5:37 PM Re: RU 2 Annular Disposal Area, Subject: Re: RU 2 Annular Disposal Area Date: Wed, 21 Mar 2001 17:37:31 -0900 From: Julie Heusser <julie_heusser@admin.state.ak.us> To: Jack Hartz <jack..hartz@admin.state.ak.us> CC: Robert Crandall <Bob_Crandall@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-1 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. I of 2 3/21/01 5:38 PM Re: RU 2 Annular Disposal Area > > 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. Do you have any comments? RPC 2 of 2 3/21/01 5:37 PM RE: Redoubt Unit #2 Annular disposal procedure Subject: RE: Redoubt Unit #2 Annular disposal procedure Date: Thu, 22 Mar 2001 17:38:38 -0700 From: Rob Stinson <RDStinson@forestoil.com> To: 'Tom Maunder' <tom_maunder@admin.state.ak.us> CC: "'osprey2@gci.net'" <osprey2@gci.net> Tom, Here is a modified procedure, with a corresponding Maximum Injection Pressure table. This table is based on a 15.5 EMW, with a 100 psi safety margin. Please let me know if you have anything else you need. Rob <<Osprey Annular Disposal Procedure.doc>> <<Max Surface Pressure.xls>> .... Original Message--- From: Tom Maunder [SMTP:tom_maunder~admin.state. ak. us] Sent: Thursday, March 22, 2001 2:11 PM To: Paul White Cc: Rob Stinson; Julie Heusser Subject: Re: Redoubt Unit #2 Annular disposal procedure > :> > > Paul and Rob, I have received your email with the intended annular disposal procedure. Thank you for including a plan to monitor the annu# on RU #1 while conducting disposal operations on RU #2. In the proposed procedure, you indicate that you would like to pump at rates between 2.5 and 4.0 bpm. For your injectivity test, it does not seem prudent to begin the test at 2.5 bpm. While this rate and higher rates may be achievable, any pumping rate must be governed by the bottom hole pressure or equivalent gradient calculated at the shoe depth at that time. The pressure/gradient is a combination of the hydrostatic pressure of the fluid column plus any pumping pressure less any frictional loss. In no case can the' gradient at the shoe depth determined on March 5 (. 81 psi/fi) be exceeded. In practice, the allowable gradient while pumping should include a safety factor to insure that disposal is not taking place in the formations immediately below the shoe. Would you please edit your procedure by allowing for a safety factor and stressing that the allowable pumping rate can only be determined when the bottom hole pressure or gradient has been calculated. I look forward to your reply. With these items addressed, I believe it possible to provide you an authorization before the close of business today. Please call with I of 2 3/22/01 4:08 PM RE: Redoubt Unit ~ Annular disposal procedure any questions. Tom Maunder, PE Petroleum Engineer AOGCC Paul White wrote: > Tom, I am attaching the procedure, I will send you a copy on letterhead if > you need it, I can't put the letterhead on my e-mail. Call me when you get > in. Thanks Paul D. White, Drilling Manager Forest Oil Corp. 907-868-2t34 pdwh ite@ fore stoil, com <<Osprey Annular Disposal Procedure. doc>> > Name: Osprey Annular Disposal Procedure. doc > Osprey Annular Disposal Procedure, doc Type: WINWORD File (application/m sword) > Encoding: base64 << File: Card for Tom Maunder >> BOsprey Annular Disposal Procedure.doc Name: Osprey Annular Disposal Procedure.doc , Type: WINWORD File (application/msword) Encoding: base64 MaxSurface Pressure.xls Name: Max Surface Pressure.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 2 of 2 3/22/01 4:08 PM R E ST OIL C O R P O RAT I © N March 15, 2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7m Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: RU #2 Surface Casing Analysis Dear Mr. Maunder, This package is in response to your request via e-mail, dated March, 6, 2001. Attached are the LOT pressure build-up graph and the surface casing and cementing review. We have analyzed the Leak off Test thoroughly. Visually, looking at a graph, the break-over point appears to be at or near 700 psi. When a derivative of this data is plotted, the change in slope of the build-up is also identified at 700 psi. The shape of pressure graph is what I would classify as a text-book example of a leak off and injectivity test. The mud weight at the time of the test was 8.90 ppg and the vertical depth was 2934' TVD. This equates to a LOT of 13.5 ppg EMW and an Injection Pressure Equivalent to 15.5 ppg, while injecting fluid at 0.5 bpm. When converted to bottomhole pressures, this would indicate that Leak Off occurred at 2,058 psi and it took 2,358 psi to put fluid away at the rate of 0.5 bpm. If you have any questions, please contact me at 258-8600. Sincerely, Rob Stinson Drilling Engineer Forest Oil Corporation Attachments: 13 3/8" Surface Casing Job Review Pressure Build-Up Graph from Leak off Test RECEIVED MAR 1 6 Alaska Oil & Gas Cons. Commission Anchora§e RECEIVED ~AR 1 6 ZOO1 Ataska Oil & Gas Cons. Commission / ReDoubt #2 Anchorage / Time Vs. Pressure ,, / I--e-- Pump Pressure, PSI,. I / / / !, - 1200 1000 800 600 400 200 0 -200 Redoubt Unit #2 13 3/8" Surface Casing Job Review Background Info The annular injection on Redoubt Unit #1 was ceased when a breakthrough of mud and cuttings was encountered at the surface. This was determined to be from a micro-annulus channel in the surface casing cement. The goal with the surface casing job on Redoubt Unit #2 was to make the necessary changes to prevent a re-occurrence of the problems. The changes were as follows: 1. Drill 18 ½" hole instead of 17 ½" hole 2. Run considerably more centralization 3. Set casing shoe at 3,200' MD vs. 1,800' MD 4. Perform a two-stage cement job 5. Reciprocate pipe through the first stage cement job Casing Job 3,212 ft of 13 3/8" casing was run smoothly to bottom. The string had 11 semi-rigid centralizers and 1 bow spring centralizer. The Halliburton ES Cementer was set at a depth of 2,017' MD. The centralization was primarily spaced out in the lower 1,500 feet of the string with a two placed adjacent to the ES Cementer. The float equipment was spaced out to provide for an 80' shoe track. Cement Jobs Once the casing was run to bottom, the rig circulated 9.6 ppg mud bottoms-up twice, while slowly reciprocating the casing. The circulation was done at 8 bpm, 650 psi. The first stage cement job proceeded as follows: 1. Dropped casing wiper plug 2. Pumped 30 bbl of water spacer 3. Pumped 223 bbl of 12.5 # lead cement 4. Pumped 171 bbl of 15.8 # tail cement 5. Dropped 1st stage closing plug 6. Displaced with 469 bbl mud. Bumped plug with 1,100 psi. Reciprocation throughout job until pipe stuck after pumping 50% of displacement. Able to land pipe properly on hanger with 120,000 lbs of downweight. Once the pipe was landed and the first stage job was in place, the ES Cementer was opened with 2,350 psi of pressure and 6 hour of circulation was commenced while the rig waited on the first stage cement to set- up. This circulation was performed at about 5 bpm and 250 psi. Cement returns were encountered at surface after circulating 140 bbl and ceased after 320 bbl. This indicates that the entire hole section was in- gauge. The second stage cement job proceeded as follows: 1. Pumped 40 bbl water spacer 2. Pumped 410 bbl 12.5 # lead cement. Cement returns started at end of lead cement job. 3. Pumped 80 bbl 15.8 # tail cement 4. Dropped second stage closing plug 5. Displaced with 300 bbl mud. Plug bumped at correct displacement 6. eressured up to 1,750psi to close the ES Cementer RECEIVED 1 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Conclusions Upon analysis, Forest Oil concludes that the casing and cement jobs went exceptionally well for the following reasons: 1. Volumes and displacements indicates gauge hole. 2. Reciprocation was possible until cement was 1,000'+ above the casing shoe (assuming gauge hole). 3. Lower portion of the string was centralized 4. Good cement returns were observed throughout second stage job. (13.0 ppg to 14.7 ppg) RECEIVED MAR I 6 Alaska Oil & Gas Cons. Commission Anchorage RU~r2 Subj,.=t: RU % \ Date: Tue, 06 Mar 2001 17:40:32 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Paul White <pdwhite@forestoil.com>, Rob Stinson <RDStinson@forestoil.com> CC: Julie Heusser <julie_heusser@admin.state.ak. us> Paul and Rob, This confirms my conversation with Rob at 1720. Julie, Jack and myself have examined the information Chuck gathered when he witnessed the leakoff test on the 13-3/8" shoe of RU #2 on Osprey. By copy of this email, we are notifying you that there is no requirement to perform an "open hole" leakoff test after drilling about 2000' of 12-1/4" hole. After the 9-5/8" casing is run and cemented, please notify us so that an inspector may witness the "pump in" or confirmation test down the 13-3/8" x 9-5/8" annulus. I would expect that this operation would be conducted in conjunction with the BOP test at that time. I also asked Rob to prepare a graph of the leakoff test information he gathered while out there with Chuck. Forest Oil Corporation should make and provide an assessment of this recently completed leakoff test data, That assessment as well as a report of the casing and cementing operation will form part of the necessary documentation to support your request for annular disposal on this well. Please call if you have any questions. Tom Maunder, PE Petroleum Engineer AOGCC Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 3/7/01 7:55 AM leak off test Subject: leak off test Date: Tue, 06 Mar 2001 16:17:28 -0900 From: Chuck Scheve <chuck_scheve@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, AOGCC To: "tom_maunder@admin.state.ak.us" <tom_maunder@admin.state.ak. us> Sorry Torn Here is what ! have done Chuck LeakOff Test Data Redoubt Shoals.doc Name: Leak Off Test Data Redoubt Shoals.doc Type: WINWORD File (application/rnsword) Encoding: base64 LeakOff Test Redoubt Shoals Name: Leak Off Test Redoubt Shoals Type: Download File (application/x-msexcel) Encoding: base64 I of 1 3~/01 7:59 AM Leak Off Test Data Redoubt Shoals #2 Leak Off BBLs 0 .25 .5 .75 1 1.25 1.5 1.75 2 2.25 2.5 2.75 3 3.25 3.5 3.75 I44.25 .75 ~ 5.25 .75 /6.25 ~7 7.25 7.5 7.75 k~.25 PSI 0 84 155 230 320 410 5OO 58O 665 735 8OO 85O 900 945 965 985 1010 1030 1045 1030 1020 1015 1020 1040 1015 1020 1025 1020 1020 1000 1010 1020 1010 1010 Shut in Time 10 sec 1 Min 2 Min 3 Min 4 Min 5 Mill 6 Min 7 Min 8 Min 9 Min 10 Min 11 Min PSI 900 865 $40 815 795 770 755 740 735 730 725 720 AOGCC Confidential Cover Sheet Page 1 ! ..... LEA 'K OFF TEST Well Name Redoubt Unit Permit tO Drill # 2003'1 Date 315/0t O~erator Forrest Oil F. ield/Unit Redoubt Shoals Company Representative Mi,ke Murray Ri; Nabors 429 , , A.O.G.C.C. Inspector Chuck Sch,eve .. LEAK OFF DATA Mud Weight. in hole (P.P.G.)~ Surface Hole T.D.I 3226 S.G. of Mud in bole 1.07 Drill Out MD 3246 Gradient of Mud in hole 0.462 Drill Out TVD 2944 ,Surface pressure, at break 800 Hydrostatic Head of Mud at T.D. 136(] Surface pressure taken to 1,040 B.H.P. at T.D. (with Leak Off pressure aDr)lied) 21,60 Surface pressure bled to (10 .seconds,). 900 E. quivalent Mud Gradient 0.73 Surface pressure bled to (t minute) 865: Equivalent Mud Spe. cific Gravity 1.69 , SuE.aqe. pressure tStabilized) 725 Equivalent Mud We. i~iht at Break (P.P.G.) 14,. 13 COMMENTS Is this a ,repeat.test No Anticipated maximu, m BH.,P at final T.D... If Yes what was last tests EMW ? T.V.D. at Total, Depth Volume of fluid pumped during L.O.T., 9 M.W. needed to balance wells max B.H.P. ~DIV/0! Volume of fl.uid returned after, bleed-off 3 Mud Weight called for i.n p.ro~3~ ram , , , ~ , , , ,, , , , , , , , i i i i I i i O Leak Off Test Redoubt Shoals 3/6/01 ~0 , . ~?00 ~400 / 1100 ~00 ~ ~ ~ ~ ~ ~L~ ~ test 0.~ 0.~ 0.50 0.75 1.~ 1.~ 1.50 1.75 2.~ 2.25 2.~ 2.75 3.~ 3.25 3.~ 3.75 4.~ 4.~ 4.50 4.75 5.~ 5.~ 5.50 5.75 6.~ 6.25 BgRRfi['8 ~ 8T~O~8 Leak Off Test Redoubt Shoals 3/6/01 AOGCC Confidential L.O.T. #1(Data) Page I BBL's or Strokes Casing test Leak Off test DettaPSt Shut-in MaxL.O.P. ~_~9~_ ~ ~ ! I ! I ~ I t i I t ' I ] [ 0.00[ 0 0 0 0 ~-~J; 0.50 170 155 75 0 i .... ~ 0.75 270 230 90 35i 17oo = -- -~-{--- 1.00 405 320 90 70 46oo ~- 1.25 540 410 9~ 120 ~s5o ~ ' ~ ' ' ' ~ ' ~-- ;---~-J--- ~.5o 6so soo so t7o ~oi 1.75 825 580 85 220 .~450. ~ ~ '. ~ r ~ ~ , ; I ', ' ~---?~--, 2.00 975 665 70 *.- 270 C 140o t 350 2.25 1125 735 65 338 a 13°0 ~ 125o --- . ' ' 2.75 1400 850 50 4731 n ~150 ; ~ ; i ' ; ', I 3.00 ~o ~oo 4~ ~o '~-' I' i i ; 3.25 1700 945 20 610 i 1000 , , ' 3.50 1850 965 20 680 P 95O 3.75 985 #REF! 753 , r 90o 4.00 1010 #REF! 825 ·800~850~ .~~ 4.25 900 ~rl~EF! s750 Leak Off les 4.50 865 ~f~EF! s 700 4.75 840 #RFF! ~ r ooo 5.50 770 [ 45o~ ~ ', ~ i , i ~~--I-~---, 400 ; · ~ , '---J---~ ' ~ ' 725 I 0 0 I I I I 2 2 2 2 3 3 BARRELS PUMPED Max Equiv Mud weight= Present Mud Weight= I Difference= 0 TVD of shoe= , Max Surface,Pressure= 0 PS! ..... Leak Off Test Redoubt Shoals 3/6/01 RU ~ Subject: RU #2 ~ \- ~ ~ \ Date: Tue, 06 Mar 2001 17:46:32 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Paul White <pdwhite@forestoii.com>, Rob Stinson <RDStinson@forestoil.com> CC: Julie Heusser <julie_heusser@admin.state.ak.us> Paul and Rob, This confirms my conversation with Rob at 1720. Julie, Jack and myself have examined the information Chuck gathered when he witnessed the leakoff test on the 13-3/8" shoe of RU #2 on Osprey. By copy of this email, we are notifying you that there is no requirement to perform an "open hole" leakoff test after drilling about 2000' of 12-1/4" hole. After the 9-518" casing is run and cemented, please notify us so that an inspector may witness the "pump in" or confirmation test down the 13-3/8" x 9-5/8" annulus. I would expect that this operation would be conducted in conjunction with the BOP test at that time. I also asked Rob to prepare a graph of the leakoff test information he gathered while out there with Chuck. Forest Oil Corporation should make and provide an assessment of this recently completed leakoff test data, That assessment as well as a report of the casing and cementing operation will form part of the necessary documentation to support your request for annular disposal on this well. · Please call if you have any questions. Tom Maunder, PE Petroleum Engineer AOGCC Tom Maunder <tom maunder~,,admin.stat'e"ak, us>'"i Petrole-~m ~eer Alaska Oil and Gas Conservation Commission 1 of 1 3/7/01 7:55 AI~ leak off test Subject: leak off test Date: Tue, 06 Mar 2001 16:17:28 -0900 From: Chuck Scheve <chuck scheve@admin state ak. us> ~ · . Organization: State of Alaska, Dept of Admin, AOGCC To: "tom_maunder@admin.state.ak.us" <tom_maunder@admin.state.ak. us> Sorry Tom Hem is what I have done Chuck Name: Leak Off Test Data Redoubt Shoals.doc Leak Off Test Data Redoubt Shoals.doc Type: WINWORD File (application/msword) Encoding: base64 r~--~ Leak off Test Redoubt Shoals Leak Off Test Redoubt Shoals Name: Download File (application/x-msexcel)] Type: Encoding: base64 I of 1 Leak Off Test Data Redoubt Shoals #2 Leak Off BBLs PSI 0 0 .25 $4 .5 155 .75 230 1 320 1.25 410 1.5 500 1.75 580 2 665 2.25 735 2.5 800 2.75 850 3 900 3.25 945 3.5 965 3.75 985 I 4 1010 4.25 1030 4.5 1045 4.75 1030 5 1020 5.25 1015 i .5 1020 .75 1040 1015 / 6.2 020 .75 1020 1020 [ 7.25 1000 ! .5 1010 .75 1020 1010 N,,8.25 1010 Shut in Time 10 sec 1 Min 2 Min 3 Min 4 Min 5 Min 6 Min 7 Min 8 Min 9 Min 10 Min 11 Min PSI 900 865 $40 815 795 770 755 740 735 73O 725 720 · AOGCC Confidential Cover Sheet Page 1 i i i i i i LEAK OFF TEST Well Name Redoubt Unit ,~ Permit to Drill # 20031, Date 315/01 Operator Forfeit Oil Field/Unit Redoubt Shoals Company Representative Mike Murray Ria Nabom 429 , A.O.G.,C.C. Inspector Chuck Scheve , LEAK OFF DATA Mud Wei,qht.in hole (P.P.G.,)t 8.9__..~01 Surface,Hole T.D., 3226 S.G. of Mud in hole 1.07,, Drill Out MD 3246 Gradient of Mud in hole 0.462 Drill Out TVD 2944 , ,S ,urface pressure at break 80._.~0 Hydrostatic Head of Mud at T.D. 1360 Surface pressure taken to 1040 B.H.P. at T.D. (with Leak Off pressure aoDlied) 2,160 Surface pressure bled to (10 seconds,) 90._9.01 Equivalent Mud Gradient 0.73 Surface pressure bled to (1 minute) 865! Equivalent Mud Specific Gravity 1.69 , S, u~e~e pressure (Stabilized) ,725i Eq,uiValent Uud,,W ,eiRh,t,, at Break (P.P.G-) ,14.13 COMMENTS Is this a repeat test No Anticipated maximum BHP at final T.D. If Yes w,h,,at was last tests EMW ? T.V.D. at Total Depth Volume of,fluid pumped, during L.O.T. 9 M.W; needed,to balance wells max B.H.P. #DIV,/0I Volume of fluid returned after bleed-off _3 Mud Weight called for i,n pro,ram , , , , , , ,, I i i i i r ii I i i ii Leak Off Test Redoubt Shoals 3/6/01 A B C D 500 400 300 200 100 0 A - Leak Off Point B - Stop Pump & Close Valve C - 10 Second Shut-in Pressure D - End Of Test I/ , --o-- Casing test /~ ~,,~~'''~ r~ ~''~ r~ -~,/. ~'~' '~ ~.~ .~ ~..~ --o- Leak Off test / // SHUT-IN TIME IN ~S (£or-x,-), ~-- Shut-in // ~r' -.-~.o.~. ~~! ....................... 0.00 0.25 0.50 0.75 1.00 1,25 1.50 1.75 ZOO 2.25 2.50 2.75 3,00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 BARREL'S or STROKES Leak Off Test Redoubt Shoals 3/6/01 AOGCC Confidential L.O.T. #1(Data) Page 1 Leak Off Test BBL's or Strokes Casing test Leak Offtest Delta PSI Shut-in Max L.O.P. 195o: 0.00 0 01 0 0 19oo I, II 0.251 70 84 71 0 185o I / 18oo i i / 0.50 170 155 75 0 175o . i i ~~ , 0.751 270 230 g0 35 17oo 1.00! 405 320 90 70 165o / 16oo / 1.25 540 410 9~ 120 155o ! 1.50 680 500 80 170; 15oo I / ~/ I 1:75 825 580 85 220; 14,5o i: 2.00 975 665 70 ~. 270 c 14oo i / 2.25 1125 735 65 338 · t3oo;13'5° ~ ,i4/ ' 2.50 1260 800 50 405: ' 125o' I 12oo 2.75 1400 850 50 473 n 115o i; 3.251 1700 045 20 '610 985 1~9"~° ~/ /~"" ' 3.50 16 0 965 20 6s0 . i · 3.75 #REF! 753 r 90o I / 4.00 1010 #REF! 825 · s5o , ' ' ~, Y ~/ ~--~_~ i Casing test ! ~, /J i 4.25 #REF! 750j/ ~ i ,/ I-- Leak Off lesl 4.50 865 ~EF! · 700 f ~ - Shut-in 4.75 840 #REF! u 65o I ~ ' '/ r 600 i / j "~ .. UaxLO. P. 5.25: 795 5OO; 5.50~ 770 5.75 755 6.00 740 300 ! 6.25 735 250: .~'/ I ., ~ ~ I 725 2o01 I 720 BAflRELS PUMPED Max Equ'w Uud Weight= , .. Present Mud We~ht= I Difference= 0 TVD of shoe= Max Surface Pressure= 0 PSI . i i i i i i ii i x '/ / ~ Casing test /~ - ~ '""J~ Leak Off tesl ~ · ./ " Shut-in / / ,'"' ,, Max LO.P. Leak Off Test Redoubt Shoals 3/6/01 Redoubt Unit//2 13 3/8" Surface Casing Job Review Background Info The annular injection on Redoubt Unit gl was ceased when a breakthrough of mud and cuttings was encountered at the surface. Tiffs was determined to be from a micro-annulus clmnnel in the surface casing cement. The goal with the surface casing job on Redoubt Unit #2 was to make the necessary changes to prevent a re-occurrence of the problems. The changes were as follows: 1. Drill 18 ½" hole instead of 17 ½" hole 2. Run considerably more centralization 3. Set casing shoe at 3,200' MD vs. 1,800' MD 4. Perform a two-stage cement job 5. Reciprocate pipe through the first stage cement job Casing Job 3,212 ft of 13 3/8" casing was nm smoothly to bottom. The string had 11 semi-rigid centralizers and 1 bow spring centralizer. The Halliburton ES Cementer was set at a depth of 2,017' MD. The centralization was primarily spaced out in the lower 1,500 feet of the string with a two placed adjacent to the ES Cementer. The float equipment was spaced out to provide for an 80' shoe track. Cement Jobs Once the casing was run to bottom, the rig circulated 9.6 ppg mud bottoms-up twice, while slowly reciprocating the casing. The circulation was done at 8 bpm, 650 psi. The fu'st stage cement job proceeded as follows: 1. Dropped casing wiper plug 2. Pumped 30 bbl of water spacer 3. Pumped 223 bbl of 12.5 # lead cement 4. Pumped 171 bbl of 15.8 # tail cement 5. Dropped 1st stage closing plug 6. Displaced with 469 bbl mud. Bumped plug with 1,100 psi. Reciprocation throughout job until pipe stuck af~ter pmnping 50% of displacement. Able to land pipe properly on hanger with 120,000 lbs oF downweight. Once the pipe was landed m~d the first stage job was in place, the ES Cementer was opened with 2,350 psi of pressure and 6 hour of circulation was commenced wltile the rig waited on the first stage cement to set- up. This circulation was performed at about 5 bpm and 250 psi. Cement returns were encountered at surface after circulating 140 bbl and ceased after 320 bbl. This indicates that the entire hole section was in- gauge. The second stage cement job proceeded as follows: 1. Pumped 40 bbl water spacer 2. Pumped 410 bbl 12.5 # lead cement. Cement returns started at end of lead cement job. 3. Pumped 80 bbl 15.8 # tail cement 4. Dropped second stage closing plug 5. Displaced with 300 bbl mud. Plug bumped at correct displacement 6. Pressured up to 1,750 psi to close the ES Cementer Conclusions Upon analysis, Forest Oil concludes that the casing and cement jobs went exceptionally well for the following reasons: 1. Volumes and displacements indicates gauge hole. 2. Reciprocation was possible until cement was 1,000'+ above the casing shoe (assmning gauge hole). 3. Lower portion of the string was centralized 4. Good cement returns were observed throughout second stage job. (13.0 ppg to 14.7 ppg) 1200 ReDoubt #2 Time Vs. Pressure r--e-Pump Pressure, PSI, ii 118t i ii il i ~1 iiii i~ ~ $118 iiiiii 111181 iiiii 8118 I~ ii I I i ~ll11118 J i! i it g ~1111 ~I i ~i 1811 ill [8 J1818 ~! ~11 III IIII Il I I! ~111 ~ II gill ll~l! Itl I llllllllllll IIIIII Ii lll~ll III i I ! Ii i l lll~ II I i I~lillll IIIII I I ll~ll I llll ~t I~11 IIII ~llll~l1181111tl811~l I 1181 ~11 ~11111illll i II I ! ! I 111 ~11~1 II I II 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 1000 80O 6O0 400 2O0 -200 Redoubt Unit #1 Annulus Abandonment Introduction This is Forest Oil's plan forward for abandoning the annulus on the Redoubt Unit #1 exploration well. This procedure addresses the inquiry in item #9 of the February 14, 2001 letter from AOGCC Commissioner Julie Heusser to Paul White. Procedure 1. Rig up BJ Services to 36" pile and the 9 5/8" x 13 3/8" annulus. Test Pumps and Lines 2. Pump 20 bbls of seawater to flush the micro-annulus channel. 3. Mix and pump 200 sacks, 42 bbls Class G Cement mixed at 15.6 ppg down the outer annulus. Monitor inner annulus for returns. Shut in outer annulus and wait 30 minutes. 4. Rig up Pressure Gauge on the 36" pile. Open and monitor pressure on the outer annulus. 5. With seawater establish injection down the inner annulus. Monitor pressures at all times. Establish injection with 20 to 40 bbls. 6. Mix and pump 550 sacks, ..114 bbls Class G thixotropic Cement mixed at 15.8 ppg. This is equal to the inner annular volume to the 13 3/8" casing shoe, plus 50 sacks. The thixotropic cement has properties that will "gel" the cement once pumped and. prevent gradient swapping in the annulus. 7. Flush Pumps and lines with 5 bbls of seawater. Shut in the inner annulus and rig down BJ Services. Depth (TVD) Depth (MD) Hole Size Casing Size/Weight Pump Via Total Mix Water Required Pre-flush Sea Water Density Cement Design 1,800 1,800 17.5" 35" 13 3/8", 68 # Annulus 36" O.D. (35.0" I.D.) 189.57# 3,026 gals 20 bbls 8.6 ppg p.,o a:LI 1st Tail Slurry Class G Cement - 13 3/8" Density Yield 2nd Tail Slurry Class G Cement - 9 5/8" Annulus Density Yield 200 sacks 15.6 ppg 1.18 cf/sack 550 sacks 15.8 ppg 1.16 cf/sack --z_oq6 l' ~ ,ok, lB ~- , o%T ~PF Redoubt ~ Report Subject: Redoubt #2 Report Date: Thu, 08 Mar 2001 07:15:14 -0900 From: Chuck Scheve <chuck_scheve@admin.state.ak. us> To: Thomas E Maunder <tom_maunder@admin.state.ak.us> Moming Tom Here is the report on the leak off test, hope this covers it. I am better at doing the work than wdtting the report. Chuck ~Leak Off Test Redoubt Shoals Name: Leak Off Test Redoubt Shoals Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 ~Leak Off Test Redoubt Shoals Leak Off Test Redoubt Shoals Name: WINWORD File (application/msword)l Type: Encoding: base64 LeakOff Test Data Redoubt Shoals.doc Name: Leak Off Test Data Redoubt Shoals.doc Type: WINWORD File (application/msword) Encoding: base64 I of I 3/8/01 8:07 AM A B C D 0.00 0.25 0.50 0.75 t.O0 1.25 1.50 t,75 2.130 2,25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 430 4.75 5.00 5,25 5.50 5.75 6,00 6.25 BARREL'S or STROKES Leak Off Test Redoubt Shoals 3/8/01 AOGCC Confidential Cover Sheet Page 1 ii ii I i I I i LEAK, OFF ,T, ES,T Well, Name Redoubt Unit #2 Permit to DHII # 20031 Date 315/01 Operator. Forrest Oil Field/Unit Redoubt Shoals Company Representative Mike Murray Ri~ Nabors 429 A.O.G.C.C.,Inspector Chqc'k Scheve , , , LEAK OFF DATA Mud Wei,qht in hole (P.P.G.)[~~ Surfac.e Hole T.D. 3226 S.G. of Mud in hole 1.07 Drill Out MD 3246 Gradient of Mud in hol, e 0.462 Drill Out TVD 2944 ,, Surface pressure at break 750 Hydrostatic Head of Mud at T.D. 1360 Surface pressure taken to 1040 B.H.P. at T.D.. (with Leak Off pressure ar)plied) 2 Surface pressure bled to (~0 seconds) ~).__~0 Equivalent Mud Gradient 0.72 Surface pressu, re bt.ed to (1 minute) 86.5 Equi,v. alent Mud Specific Gravity 1 Surface pressure (Stabilized)i 725 Equ!valent Mud Wei.qht at Bm,ak (P.P.G.) 13.81 COMMENTS is thi,s a repe,at test N.~o Anticipated maximum BHP at final T.D. If Yes what was last tests EMW ? T.V.D. at Total Depth Volume of flui,d pumpec!., durjn~t L.O.T. 8.5 M.W. needed to balan.ce wells max B.H.P. #DIV/0! i Volume of fluid returned after bleed-off 3 Mud Wei~;lht called for in program , , , , ,, i I i i i i ii ii i I Leak Off Test Redoubt Shoals 3/8/01 AOGCC Confidential L.O,T. #1(Data) Page 2 BBL's or Strokes Casingtest Leak Off test DeltaPS! Shut-in MaxL.O.P, !{ 195o[___j ! ~ I I ! . i I I I ' ____~_~_ ~____~___ o.oo d o o oil 4~! ! ~ , ;,, , ~ . ;, ; , ; , , ---k--k--~--,, . o 1800 0.75 270 230 90 35 4700 1,00 405 320 90 70 t650 1.25 540 410 90 t20 1.50j 680 500 80 170 1500 1.75i 825 580 85 220 2.001 975 665 70 270 C 4400 2.50 1260 800 50 405 s 4250 I i ~~ ~, , ! I , i 1200 2.75 1400 850 50 473 - ¥15o, , 3.00 1550 900 45 540 g 4100 3.25 1700 945 20 610 lO5O 3.50 1850 965 20 ~80 r 3.75 985 ~EF! 753 r 4.00 1010 #REF! 825 s s~=o 4.25 900 #REF! s 78o~~ i~,~,-i ~ .~' I. ~ ~,"~ I i i I~"~'''h _ . Leak Off test 4.50 865 #REFt 4.75 840 ~EF! '1 u c~ ~ ' I --- · Max LO,P. 5.00 815 · ~ 5,25 7951 5,50 770~ 45~ 6.00 740: 725 200 0 0 I ! I I 2 2 2 2 3 3 3 3 ¢ 4 4 4 BARREL8 PUMPED Max Equiv Mud Weight=- Present Mud We~ht= , t Difference= .... 0 TVD of shoe= ,, M~ Su, ,,~Pressu,m=, , 0 PSi .................... Leak Off Test Redoubt Shoals 3/8/01 CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: Supervisor: [] Initial Casing Shoe Test Reason(s) for test: [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Descri~.~B.T~-'~'/ Casing Setting Depth: 3,226' TMD Hole Depth: 3,246' TMD 2,935' TVD 2,944' TVD EMW - Pump output = 0.0357 bps Mud Weight: 8,9 ppg Length of Open Hole Section:_., 20' Leak-off Press. + Mud Weight = + 8.9 ppg 0.052 x TVD EMWforopenholesection 15~g~ -- Fluid Pumped = 8.0 bbl %40~psi 1,30O psi 70O ~ TIME LINE 30Op~ Op~, 024 6610248~0~ 1 t 111222223333344444~MIr'J TT ~Tl~ll~lgl~gg'g~22'~'~'-~"~"/223'a3~alla4 kkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkk~ '''~- .... '_-'_-~ -~:- .... ... ~ ~_._ ._ :~:..._.~.;:_. ~ ......... .. ............. .__ ~.~.=.:........_ ~_ ~ ~ _._ L__ ~ ~,____ ~__~__~ ~ kkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkk kkkkkkkkkkkkkkkkkkkkkkkkkkkkk~kkkk STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time tine above LEAK-OFF DATA CASING TEST DATA MINUTES MIN UTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE F ........... ~"'~i'~'~-'l .... '~'~[":~I ,,"::~ ........ l'"iF~'~"'[ .... ~'~i' .... I.~ .......... I._ .... ~ .... .I, ........................ ~ ........~. ............... ; ; 14.tks { 155,~i~ ~ I 14stks ~ 170 psi · l .................... ~ 28 stks 'i ........ 320 psir"-; ................................. '~: Il' ....... ----, I I---~--- ..... 4, I ....... .,1. ..... . ,4 I ~ ......... 4 ........~--t, I .............. : , 42 stks I 500 psi ',? ?;~ | 42 stks ~ 680 ~.si I. ............ .4- ............ · ........ *-~,---. .... ~ ........................ ,,' ................ t ~ : 66stks ~ 665ost , ~ .} r_;. ............ '!'., ........ 84 stks ~', ...... 900=~'~"iSl, ......... -~- ......... ' ........ ~- .... ~ ~' ............. 1 .............. r .......... s'"'.'"l ! 98stks i 965 si ............................... .pa .................... 112 stks 1,010 psi j , 140 stks 1,020 ..~.j: '~ 168 stks ............ ~ t82 stks '-~'t~'~'~.~.'! 210 stks 1,010 psi l 1 SHUT IN TiME SHUT IN PRESSURE ........ 1_ ........................ . ..... 0.0 min 1,010psi i ...... ~..~.&. ............. .& .......... .~ ..... a } 1.0min ................. ..86_6.j~._.i.... [' 2.0 rain 840psi [' ....... '.'''~ .............. 'f ......... ~'. .... 4.0 mln '_.7_9..5_.ps_.1..., !..=_:__.;.- ,+ ............. o.u mm , 770.E~i 6.0 min ~ 755 psi : I.~... ......... ,a....-.. ........ ,J ............ ...z 7.0 min i 740 psi j ,. ........................... 8.0 minj 735 psi ] ........ ~ I- ........... ,! ....... * ...... · ' , I · 90mtn , ~ 730~m ! · ~! ...... ~ ......... ~- .......... ..w- . 4 ' i ! I ~ o.o m. ~_n..L ......... __L._7.2_S__r~_t__: I i ............. · i ............... i. ............. I , ! SHUT IN TIM,E_j SHUT ........ IN PRES8URE .... ........... , .............. · I i 1,0 mln ~ ~ ~--~-~ .... ~---~ ............... F ............... , Z.U mtn . , ............ :::::::::::::::::::::::::::::::::::: .......... ...~.=:=,= ~~-~- ............... ~ .............. 5.0 min I ~ J ............. -~ .............. ~ ............... 6.0 min ! ~ ..... - ......... ~- ............ r ................ 80 rain ~ .............. .............. [ ................ 9 0 min , I , -F~;~--"! ............... t ............... 1u.u mln , , , .............................15.0 min i ~ ................ 20.0 min L [ ............. ............. ['" i :::::::::::::::::::::::::::::::::::::::: NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: Supervisor: [] Initial Casing Shoe Test Reason(s) for test: [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Descrip~9.7 ppf~ Casing Setting Depth: 3,226' TMD 2,e3s' TVD Hole Depth: 3,246' TMD 2,944' TVD Mud Weight: 8.9 ppg Leak-off Press. Length of Open Hole Section: 20' 1, 5~p~s~i + 8,9 ppg EMW - 0.052 x TVD + Mud Weight EMW for open hole section ~g~ __ Pump output = 0.0357 bps Fluid Pumped = 8.0 bbl TIME LINE op~ ..... I I I p ,TTi --e-- LEAK-OFF TEST ia,-CASING TEST .... LOT SHUT IN TIME ~, ~ CASING TEST SHUT IN TIME ,/[ ~ TIMELINE / /' ~',:) ~ /,/ ~ ~r Osll[ 14~26~42~l~56~70SlkS4Sg(98~ 112 126140 154168182 196210224 238252 266280 294 30832233~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE y .~ .= 'f' ~ . 1 I U SI;KS I U piti .,' ........... -r, --q-~-~--!--~_s_-~T~.~T ',' i 42 stks 500 psi j ~ 70 stks 800 ~m ~ ........... .~ ................ r.:..._~ : 84 stks . 900.E~...I j ~_ ........... .p ............ ,,- ........ ;---, .......... ,.[._.9..8_s_.__~.s_j 965 I?._[..j i 112stks 1,010p. si i ..... ~'~-'T'i~'~'~' "~;~ ~i'i ............. T "i;i4T~'t~s- "1-;~-'.~.'~i'] ~ 1~ s~s 1,020 t 1. ~ 1,015 osi ~82 s~. 1,025 ~i ...... ~[..i~p~.~. j,~2~.p.~L~ 210stks 1,010~i ! ..... ~ ........ ~ ........... 4 ............ ----~ .... ........... ...... . ........ ~ ............. SHUT IN ~ME ~HUT IN PRESSURE 0.0 min 1,010psi 1.0 rain ~ ~ 865 psi ............ . .... . .... 2.o min ~.0 rain . 81S~i 4.0 m~n 5.0 min , 770 [ 7.omm ............. LT~M... e.o m~n ................. 9.0 min ~ 730 ~i CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .............. l"'~'~'~li~'-" .... iJ'~i ..... I- ................................... ~ ....~-"1 ! 14 stks 170 ~Sl i 42 stk8 680 psi .............. I ............... I' ............ ~'"I , 56stks , 975.m h ........... I"~'~'~"l'i;~,'~¢~(I ............ ~ .............. f ........ ' ..... ! I I ............ ............. ., ............... ~ ............... I I .............. -I ............... F ................ I I i I ............... , I ............. ,,' ............... r ............... ............. .............. i ............... ,1 , , SHUT IN TIME~ SHUT IN PREISURE ~... ....... ..- ...... ... .................... ..-.-.~ 0 0 mln ! [ 1,850nsl I r..7.,.. .......... ' I I 1.0 mln , , I---~.-~ ..... ---4 ............... ~ ............... >',U mln I I r"~.'0-~r~"t .............. ,~ ................ .............. ~ .............. i- ............... 40min · h--: ..... :-t ............... 1 ................ 5.0 m~n .............................. 6.0 minl [ ................ i F'~b-T~FF¢'I .............. 7 .............. I---;-' .........4 ..............-F .............. 8.0 rain · . ., ,~'-~:'o'~r~"l ............. t" ............. ' I"s::..:~. .... :"t .............. f ................ I ~U.U mln , , · I i 115.0 mln I I t' .......... .'"~ ............... 20.0 mln! l- ............................ 25 0 min ~ .... : ......... t ............. f ............... 30 0 min, , ~. .... .' ......... J .............. /, ................ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY LEAK-OFF TEST 1,t00 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0.0 rain 2.0 min 4.0 min 6.0 rain 8.0 min 10.0 min 12.0 min SHUT IN TIME MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor DATE: March 5, 2001 FROM: Chuck Scheve, SUBJECT' Petroleum Inspector Leak Off test Redoubt Shoals #2 PTD # 201-031 Monday, March 5, 200._'1; I traveled to Forrest Oil's Osprey Platform and witnessed the casing pressure test and the Leak Off test of the surface casing shoe on the Redoubt Shoals ~ well. ! arrived on the platform and found the rig tripping in the hole to the ES-cementer. Successful casing pressure tests were performed prior to and after drilling the closing plug, Drill pipe was then tripped in the hole to the float collar and the well was circulated clean, At this point a 30 minute 3000 psi test of the casing was performed with the rig pump with no loss of pressure observed. A second pressure test to 1800 psi was conducted using the Swaco/DSR injection pump for comparison to the leak off test. After drilling the float equipment and 20' of new hole (2944 TVD) the well was circulated clean with a balanced mud weight of 8.9 ppg. The leak off test was conducted at a pump rate of ~ barrel per minute with leak off to the formation at approximately 750 psi or a 13.8 ppg equivalent mud weight. An additional 6 barrels were pumped after leak off was attained with a maximum pressure of 1040 psi. The pumps were shut down and the pressure observed at 1-minute intervals for 11 minutes. The pressure declined rapidly for the first 6 minutes to 755 psi and then slowed with a final reading of 720 psi. The leak off test data is attached for reference as all points wouldn't plot on the graph, Summary: I witnessed the casing pressure test and Leak Off test of the surface casing shoe on Forrest Oils Redoubt Shoals #2 well on the Osprey Platform. Attachments; Leak Off Test Redoubt Shoals #2 3-5-01 CS Leak Off Test Data Redoubt Shoals 2 of 2 3/7/01 7:55 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser Commissioner THRU: Tom Maunder P. I. Supervisor FROM: Jeff Jones DATE: March 3, 2001 SUBJECT: Petroleum Inspector Surface Pipe Cementing Forest Oil / Nabors 429 Redoubt Unit #2 PTD 201-031 Redoubt Shoal Field Thumda¥,_Marcb~..1,20.,0! ;, I traveled to Forest Oil Company's Osprey Platform to witness the surfaCe pipe cementing operation on the Redoubt Unit fK2 well, being drilled by Nabors Rig 429 personnel. On my arrival at the location, 13 3/8" 68# casing was being run in the open hole. I spoke with operator representatives, Mike Murray and Rob Stinson, regarding the casing particulars and their plan for the cementing operation. They indicated that the cement volumes calculated for this operation were based on an 18 %" open hole size with t00% excess, and they would cement the surface pipe in two stages using a DV port collar. No problems were noted while running the casing to TD, and i noted that the bottom of the casing collar below the DV cementer and the collars on the two joints of casing above the DV cementer were "strap welded". This was done to prevent the casing from backing out while drilling out the plug in the stage tool. The drilling mud was then circulated until it weighed 9.6 PPG in and out of the hole. At 0915 hrs. on 3/2/01 BJ Services began the cementing operation while the casing was slowly reciprocated. The first stage of the cement job consisted of 223 BBLS of 12.5 PPG class G lead cement slurry, followed by 171 BBLS of 15.8 PPG class G tail cement. The cement pump rate was approx. 5.7 BBL/min. at 900 psi. The BJ Services personnel experienced some problems with the automatic density control apparatus on their unit, which caused some short delays, and they reverted to manual density control. Approximately 90 BBLS of fluid was lost during the first stage. The cement was displaced at approx. 8 BBLS/min. with the rig pumps and the casing began "sticking" during reciprocation. The casing was landed and I Nabors 429 RU witnessed the shut off plug "bump" at 3365 total strokes with a pressure increase to 1100 psi. at 1236 hrs. .~ ~,C ,,~ ~c~ ~-\~,.~ The DV cementing tool was then opened at 2350 psi with the rig pumps and I witnessed 13.3 PPG green cement circulated to surface at 1031 strokes (approx. 80 BBLS). The cement was then allowed to set for 8 hrs. while more water was delivered to the platform. The second stage cement job began at 2000 hrs. and consisted of 550 BBLS of 12.5 PPG class G lead cement slurry followed by 95.5 BBLS of 15.8 PPG class G tail cement. Problems with the BJ cementing unit again caused minor delays during this operation. The BJ unit used for this job is new, and still has a few "bugs"to be worked out. Robert Moore with BJ Services did a good job of keeping the job moving through these problems. I witnessed green cement returns to surface that gradually increased from 12.3 PPG to 14.7 PPG when the cementing ended. I witnessed the closing plug "bump" the DV cementer closed at 1750 psi and 2159 total strokes at 2314 hrs. SUMMARY: I witnessed a surface pipe cementing operation on Forest Oil Company's Osprey Platform well Redoubt Unit #2, in the Redoubt Shoal Field. A~chmen~: Forest Oil Corp. Cementing Report (3) BJ Services Cement Job Report (2) BJ Services Cement Unit Strip Chart ,C, O. NFIDENTIAL Nabors 429 RU Re: [Fwd: RD #2] Subject: Re: [Fwd: RD #2] Date: Wed, 14 Feb 2001 10:04:35 -0900 From: Robert Crandall <Bob_Crandall@adrnin.state.ak.us> Organization: DOA-AOGCC To: Julie Heusser <julie_heusser~admin.state.ak.us> CC: Tom Maunder <tom_maunder@admin.state.ak. us>, Stephen F Davies <steve_davies@admin.state.ak.us>, Dan Seamount <dan_seamount@admin.state.ak.us> Julie: Currently, there occurs to me, two possibilities to explain the RU 91 incident, 1) the surface cement job was lousy and it broke down at the shoe and a channel was easily established to the surface and 2) the cement job was good and the formations broke down. We know what reasonable frac gradients are for the Cook Inlet (sands .5-.65, shales .75-.9 lb/ft) sediments are and we should be able to find out the rates and pressures of the annular disposal for RU #1 are. An analysis of this information and the a detailed history of the RU 1 cement job may be sufficient to color our thinking as to which of the above two possibilities are most likely. I would be inclined to ask Forest to perform the work and review it with them. Special attention should be paid to at least three aspects of the surface hole for RU ~2: 1) The RU~I well disposed of a large volume of oil based mud, which will serve as a distinctive tag for this material. The possibility that this material could travel 800', and be in detectable quantities at the RU %2 location are low and I'm ambivalent about requiring a mudlogger for that purpose, but I think it is reasonable to require the cuttings be closely examined for OBM stain.2) A open hole caliper should be run with special attention paid to potential wash outs. The results should be used to calculate cement volumes. Cuttings from washed out zones should be closely examined for OMB stain.3)The surface cement job history and LOT should be closely reviewed. Also the rates and pressures Forest will pump should be established. Let me know if you'd like to discuss any of these points. RPC Julie Heusser wrote: > Morning Guys, > I am forwarding Tom's reply to y'all (southern for you all) and would appreciate your > comments and idea. To what extent has the annular disposal operations on Redoubt Unit > # 1 affected the surface formations . I know this is difficult question to answer but > perhaps the worst and best case scenarios could be defined. What are your thoughts on > requiring additional monitoring by the wellsite geologist/mudlogger/? to verify the > integrity/non damage of the shallow formation. What could/should be monitored? What > criteria should/would be used to determine that no problem exists? > > Please don't limit your response to my questions. If there are any other points 1 of 4 2/14/01 2:23 Pi~ Re: [Fwd: RD that > should be raised and discussed, please consider them too. > > Cheers > Julie > > Tom Maunder wrote: > > > Julie, > > I like the proposed revisions to the surface cementing program for RU #2. "Like" > > probably can't be the basis for an approval, but they are proposing to do what in > > my experience greatly helps achieve the desired competent cementing and isolation. > > They are proposing deepening the setting depth of the casing and performing the > > cementing operation in 2 stages. Both stages will help isolate the RU #2 wellbore > > from the "environment", but the 1st stage will be the critical stage to isolate the > > proposed "disposal shoe". > > They are significantly deepening the proposed shoe depth by some 1100' tvd and have > > a lateral wellbore separation from RU #1 of some 800' at the proposed shoe depth. > > Centralizing the casing helps provide a space on the "low side" where cement can > > displace the mud as it is being pumped. Moving the pipe while cementing further > > aids the mud removal by changing the particular geometry present at a given point > > in the hole. It is indicated that they plan to use "rigid" centralizers which are > > not subject to collapse against the low side of the hole. Centralizing and > > reciprocating during the 1st stage cementing operations should help promote > > achieving the planned isolation. > > For the 2nd stage, it will not be possible to reciprocate the pipe, but > > centralization should still be employed. The same positive effects of > > centralization realized on the 1st stage should also be present for the 2nd stage. > > Cement isolation for the upper section of the pipe is dependent on fluid to fluid > > swap out. Fluid density differences and use of a large excess slurry volume are > > the usual factors involved with successful 2nd stages operations. > > Pumped as indicated, the 2nd stage should be successful in cementing the remainder > > of the RU #2 wellbore to surface. My experience with 2nd stages is that if the 1st > > stage is successfully placed, it will provide a "bottom" for the 2nd stage and > > usually be successfully placed as well. My only concern is if past activities on > > RU #1 could have altered the subsurface and potentially compromise the ability to > > cement RU #2. I don't have an answer for that question. I think the information > > gained drilling the surface hole will go a long way to providing the answer. > > > > Hope this helps...please let me know what else i can provide. > > > > Tom > > > > Julie Heusser wrote: 2 of 4 2/14/01 2:23 Pi~ Re: [Fwd: RD #2] > > > Thanks for the info Tom. What's your opinion of their proposal? > > > Julie >>> > > > Tom Maunder wrote: > > > > Julie, > > > > This is the note I received from Rob Stinson in reply to my email > > > > questions. > > > > Tom > > > > Subject: RE: RD #2 > > > > Date: Tue, 13 Feb 2001 12:39:55 -0700 > > > > From: Rob Stinson <RDStinson@forestoil.com> > > > > To: 'Tom Maunder' <tom maunder@admin.state.ak.us> > > > > CC: Paul White <PDWhiteSforestoil.com> >>>> > > > > Tom, > > > > At this point, it looks like we will be spudding Redoubt Unit #2 early > > > > next week, around February 19th. You are correct about the displacement > > > > number for the 2nd stage cement on the surface job being in error. You are > > > > also correct that the stage collar will be set at 2,000 MD. The reasoning > > > > for the increased hole size is to add a significant amount of centralization > > > > to the 13 3/8" surface casing. The positioning and amount of centralization > > > > will be determined once we have a feel for the condition of the 18 1/2" > > > > hole. We intend on reciprocating the surface pipe as long as possible > > > > through the 1st stage of the cement job, to increase the chances of a solid > > > > shoe job. When we performed the LOT on the surface shoe of RU al and the > > > > initial annular injection test we did use the rig pump. We will use the > > > > MI/Swaco injection pump on RU#2 to reduce the flowrates down to near what > > > > you suggest. If you have any other question or need more clarifications > > > > please contact Paul or me by e-mail or phone. > > > > Thanks, > > > > Rob Stinson >>>> > > > > > ..... Original Message > > > > > From: Tom Maunder [SMTP:tom maunder~admin.state.ak.us] > > > > > Sent: Saturday, February 10, 2001 11:02 AM > > > > > To: Paul White; Rob Stinson > > > > > Subject: RD #2 > > > > > Paul and Rob, > > > > > I was in reviewing the RD #2 plan. When does it look like you will > > > > > propose to spud?? I understand the platform is rather crowded with > > > > > testing to commence on R#1. > > > > > Based on preliminary review, I believe your requests/proposals to > > > > > increase the surface hole size and depth will be granted. > > > > > Please have a look at BJ's presentation for your surface cement job. It > > > > > looks like the displacement volume for the 2nd stage is the same as the > > > > > 1st. It would be helpful to have the stage tool depth stated in your > > > > > program. From the BJ information I was able to determine that it was > > > > > 2000'. > > > > > It would also be helpful to have a larger (longer?) discussion on the > > > > > casing and cementing operation. In other notes and the annular disposal > > > > > application you talk of increased centralization and reciprocation to 3 of 4 2114101 2:23 PM Re: [Fwd: RD #2] > > > > > better achieve shoe isolation. I think a discussion of those points is > > > > > important. > > > > > There will be a couple of other points... > > > > > ...If the 2nd stage cement doesn't get to surface, please notify us. It > > > > > has been our practice on the slope to have an Inspector witness "top > > > > > jobs". If such an operation were necessary, I presume it would be > > > > > accomplished using a small diameter string run into the annulus to the > > > > > TOC. Please confirm this. > > > > > ...With regard to the LOT after drilling out. If I remember correctly, > > > > > both the casing test and LOT test on R#1 were performed using a small > > > > > volume test pump. I remember being surprised by pressure versus time on > > > > > the plot. I have checked our guidelines and it is recommended to "pump > > > > > at as low a rate as practical, but sufficient to overcome filtration > > > > > losses" A minimum rate of .25 bpm is given. Last time I understand > > > > > that the mud pumps were equipped with large liners that made low rate > > > > > pumping difficult. Is it possible to use the cementing unit?? If not, > > > > > how would you propose to be able to pump at say .25 to .5 bpm?? I look > > > > > forward to your reply. >>>>> > > > > > Good luck on R#1. > > > > > Tom Maunder << File: Card for Tom Maunder >> Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Ma under Petroleum Engineer <tom maunder~admin, state.ak, us> >>>> >>>> Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. An ch ora ge AK 99501 USA Additional Information: Last Name Maunder First Name Tom Version 2.1 Fax: 907 276-7542 Work: 907 793-1250 Conference Software Address 4 of 4 2/14/01 2:23 PM More Thoughts Subject: More Thoughts Date: Wed, 14 Feb 2001 16:23:28 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Julie Heusser <julie_heusser@admin.state.ak.us> Julie, As we have worked to develop the latest letter, I have had various thoughts for providing quality assurance for the proposed operations on RU #2 (or is it RU #@). Do we want to witness the running and cementing of the surface casing on RU #2? We do not normally do so, but doing so may not be out of line. Having two representatives may not be out of line. Should the witness(es) be myself and an Inspector??...2 Inspectors?? We will likely have an Inspector out there for the BOP test. After that there are several operations that could be witnessed. ---casing pressure test prior to drilling out the stage tool ---casing pressure test after drilling out the stage tool (likely when the float collar is tagged) ---casing pressure test after partially drilling out the float joints --,leak off test---I have found guidelines for conducting such tests in the PI manual. We could provide them to Forest, After drilling ahead, we could require them to perform an open hole leak off test with a couple of thousand feet of hole drilled. The amount of open hole could correspond to what is intended to be open after the 9-5/8" casing is cemented. Anadarko performed such a test on their initial Lone Creek well and PPCo routinely performs such tests when increased mud weights are possibly needed for the Kuparuk. ! would welcome the opportunity to discuss these ideas/points with you. I do believe we need to insure to the best of our abilities that quality iS assured on RU #2. Thanks. Tm Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of I 2/15/01 2:44 PM February 13, 200;i 0905 Call 'from Rob Sanson... presently testing on RU#1 ... then completing.., did not use a pump.., will send a reply to the email. He had just returned from Houston over the weekend. Well after RD ~2 will be the disposal well... Rob says he and Paul have lobbied to ddll the disposal well prior to RD #2, but upper management wants to prove up another fault block. Discussed that approval of annular disposal on RU #2 was not assured just with the proposed changes. He agreed and asked what the status of discussing the RU #1 disposal issue was. I told him we were nearly completed with a review of their submitted information and a response was being prepared. When the response is ready, he offered to come pick it up since they are keen to resolve any repair issues. He further indicated that Paul White had on several occasions attempted to contact Julie to discuss the issues. He said Paul had not been able to speak with her. He indicated that an attempt had been made to establish "reverse flow" by pumping seawater down the 36" pile x 13-3/8" annulus. No date information was given, nor were any rate, volume or pressure information provided. He did not have any specific information since he indicated he was not involved with that operation. ((This may indicate that it occurred while he was in Houston.)) His only comment was that they used the injection pump and understood "the rate and pressure were Iow and the volume pumped small". February 14, 2001 ~1030 Call from Paul White and Rob stinson.., most concerned regarding my memo to Rob on RU#2... testing process on RU#1 is just about done.., in final shut in... completion next.., plan to run an ESP with an external packer on the tubing will a SSSV... spud of RU#2 potentially Feb 19 to 20... application for annular disposal for RU#1... DV collar is an ES type.., pressure activated.., plan to circulate cement to surface on the 2nd stage prior to dropping the plug...will result in a lot of cement returns at surface Attempted to pump down the pile x 13-3/8 with seawater at .5 bpm and 300 psi, pumped several barrels. Pile x 13-3/8" is open to wellhead room with no pressure shown, no pressure on IA as well. Anxious to respond to whatever requirements we might have. Told him we are reviewing all information we presently have and Julie is preparing a response. I indicated i would speak with Julie and we would likely be in contact later today or tomorrow. RE: RD #2 Subject: RE: RD #2 Date: Tue, 13 Feb 2001 12:39:55 -0700 From: Rob Stinson <RDStinson@forestoil.com> To: 'Tom Maunder' <tom_maunder@admin.state.ak.us> CC: Paul White <PDWhite@forestoil.com> Tom, At this point, it looks like we will be spudding Redoubt Unit #2 early next week, around February 19th. You are correct about the displacement number for the 2nd stage cement on the surface job being in error. You are also correct that the stage collar will be set at 2,000 MD. The reasoning for the increased hole size is to add a significant amount of centralization to the 13 3/8" surface casing. The positioning and amount of centralization will be determined once we have a feel for the condition of the 18 1/2" hole. We intend on reciprocating the surface pipe as long as possible through the 1st stage of the cement job, to increase the chances of a solid shoe job. When we performed the LOT on the surface shoe of RU #1 and the initial annular injection test we did use the rig pump. We will use the MI/Swaco injection pump on RU#2 to reduce the flowrates down to near what you suggest. If you have any other question or need more clarifications please contact Paul or me by e-mail or phone. Thanks, Rob Stinson ..... Original Message .... From: Tom Maunder [SMTP:tom_maunder~admin.state. ak. us] Sent: Saturday, February 10, 2001 11:02 AM To: Paul White; Rob Stinson Subject: RD #2 Paul and Rob, I was in reviewing the RD #2 plan, When does it look like you will propose to spud?? I understand the platform is rather crowded with testing to commence on R#1. Based on preliminary review, I believe your requests/proposals to increase the surface hole size and depth will be granted. Please have a look at BJ's presentation for your surface cement job. It looks like the displacement volume for the 2nd stage is the same as the 1st. It would be helpful to have the stage tool depth stated in your program. From the BJ information I was able to determine that it was 2000'. It would also be helpful to have a larger (longer?) discussion on the casing and cementing operation. In other notes and the annular disposal application you talk of increased centralization and reciprocation to better achieve shoe isolation. I think a discussion of those points is important. There will be a couple of other points... ...If the 2nd stage cement doesn't get to surface, please notify us. It has been our practice on the slope to have an Inspector witness "top jobs". If such an operation were necessary, I presume it would be accomplished using a small diameter string run into the annulus to the TOC. P/ease confirm this. I of 2 ~., ,..With regard to the LOT after drilling out. If I remember correctly, .....:.,,'..__~..~oSb ttle-ea.sin_q test a/zd.._LOY~~ R#l 2/15101 2:53 PM RE: R,~ volume test pump. i remember being surprised by pressure versus time on the plot. I have checked our guidelines and it is recommended to "pump at as Iow a rate as practical, but sufficient to overcome filtration losses". A minimum rate of .25 bpm is given. Last time I understand ~lOf fhe ~ud pgmps were equipped with large liners that made Iow rate rlumplng difficult. Is it possible to use the cementing unit?? If not, how would you propose to be able to pump at say .25 to .5 bpm?? I look forward to your reply. Good luck on R#1. Tom Maunder << File: Card for Tom Maunder >> 2 of 2 2/15/01 2:53 PM Re: Redoubt UnitADEval.xls Subject: Re: Redoubt UnitADEval.xls Date: Mon, 12 Feb 2001 10:54:00 -0900 From: Julie Heusser <julie_heusser~admin.state.ak.us> To: Wendy D Mahan <wendy_mahan~admin.state.ak.us> CC: Dan Seamount <dan_seamount@admin.state.ak.us>, Camille O Taylor <cammy_taylor~admin.state.ak.us>, Tom Maunder <tom_rnaunder~admin.state.ak.us> Wendy, Thanks for your comments and list of further questions. Some I can answer now and some I can not. Have a wonderful day at the beach with your family! More Later Julie Wendy D Mahan wrote: > Hi Julie, I guess at this point I have more questions. I'm sure some probably have already been answered. 1. 142ho gave the authorization to inject in the first place? The 10-403 Tom and I looked at after the event was unsigned. 2. Have the Vetco Gray reps. comments been confirmed or denied by the North Slope operators? If confirmed, where is water surfacing on the North Slope? Could Vetco Gray be held responsible in any way if they gave bogus info to Forest? It seems as though the operator may have been misled. 3. What level of communication went on between the platform and town? Was town notified on the 16th that more than seawater was surfacing? If not, when did they become aware of the situation? 4. Why did the platform continue to inject after town told them to stop? Who's the drilling contractor and what level of experience did the employees have that were injecting fluids ? As far as penalties go, you couM fine them up to $5,000/day either for negligence or knowingly violating our regs. If any documents were falsified, they could also spendjailtime and/or be fined for that. AS 1 of 3 7/26/01 11:33 AM Re: Redoubt UnitADEval.xls 31.05.150. The operator should certainly have not!fled us and ceased injection on the 16th. Probably on the 13th. The rest of my family arrived and I'm heading to the beach today. Will be back Thursday afternoon. Wendy Original Message ...... From: julie_heusser~admin.state, ak. us Date: Sunday, February 11, 2001 6:06 pm Subject: Redoubt UnitADEval. xls Hello All, Attached is a workbook comprised of four spreadsheets that I have put together to help assess the Forest Oil Redoubt Unit #1 annular disposalproblem. I wouM appreciate your thoughts and comments on the summaries. Spread Sheet #1: Daily Summary of Annular Disposal Operations SS #2: a work sheet to calculate injection period - probably o ly of interest/use to me. SS #3: This is pretty much the meat of my eval. It combines information that Forest has presented to us. FYI: the term 'flowback measurement taken" represents the number of times during the injection operation that the volume and rate of fluid flowback was measured by the rig. I noted this because it demonstrates the number of opportunities the rig had to recognize that an annular disposal problem existed. This prints out best on legal size paper. SS #4: This summarizes the number of"flowback measurements" taken. As you can see there were quite a few. To fill up the equivalent of a five gallon bucket (a little bigger than the trashcan in most of our 2 of 3 7/26/01 11:33 AM Re: Redoubt UnitADEval.xis > > offices...) in less than 30 seconds is a sign~cantflowback volume > > that should be pretty di[~cult to ignore. > > Cheers > > .lulie 3 of 3 7/26/01 11:33 AM Redoubt UnitADEval.xls Subject: Redoubt UnitADEval.xls Date: Sun, 11 Feb 2001 15:06:06 -0900 From: julie_heusser~admin.state.ak.us To: Tom Maunder <tom_maunder~admin.state.ak.us>, Wendy D Mahan <wendy mahan~admin.state.ak.us> CC: Dan Seamount <dan_seamount~admin. state, ak.us>, Camille O Taylor <cammy_taylor@admin.state.ak.us> Hello All, Attached is a workbook comprised of four spreadsheets that I have put together to help assess the Forest Oil Redoubt Unit #1 annular disposal problem. I would appreciate your thoughts and comments on the summaries. Spread Sheet #1: Daily Summary of Annular Disposal Operations SS #2: a work sheet to calculate injection period - probably only of interest/use to me. SS #3: This is pretty much the meat of my eval. It combines information that Forest has presented to us. FYI: the term "flowback measurement taken" represents the number of times during the injection operation that the volume and rate of fluid flowback was measured by the rig. I noted this because it demonstrates the number of opportunities the rig had to recognize that an annular disposal problem existed. This prints out best on legal size paper. SS #4: This summarizes the number of"flowback measurements" taken. As you can see there were quite a few. To fill up the equivalent of a five gallon bucket (a little bigger than the trashcan in most of our offices...) in less than 30 seconds is a significant flowback volume that should be pretty difficult to ignore. Cheers Julie ~Redoubt UnitADEval.xls Name: Redoubt UnitADEval.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 1 of I 7/26/01 11:32 AM BEGIN BEGIN TOTAL TIME TIME END TIME END TIME HOURS INJECTION (HOUR) (MINUTE) (HOUR) (MINUTE) (MINUTES) MINUTES TIME 17 25 19 10 120 -15 105 19 20 20 15 60' -5 55 20 15 21 45 60. 30 90 17 25 21 45 240' 20 260 7 40 7 55 0 15 15 7 55 9 15 i20 -40 80 9 15 10 35 60 20 80 7 40 10 35 180 -5 175 23 36 23 53 0i 17 17 23 53 0 47 60 -6 54 0 47 2 6 i20! -41 79 23 36 2 36 180 0 180 11 40 11 55 0 15 15 11 55 13 5 120. -50 70 13 5 14 25 60 20 80 11 40 14 25 ................ 1~0 -15 165 18 0 18 20 ~ 20 20 18 20 19 50 ~0 30 90 19 50 21 15 i~0 -35 85 18 0 21 15 180 15 195 7 10 7 30 0 20 20 7 30 8 45 60 15 75 8 45 10 5 120 -40 80 7 10 10 5 ......... i8~ -5 175 23 0 23 20 0 20 20 23 20 0 35 60 15 75 0 35 2 15120 -20 100 23 0 2 15180 15 195 16 0 16 20 0 20 20 16 20 17 45 ............... 6~ 25 85 iii.i'_.ii..i.iiii 16 0 19 25!~0 25 205 2 25 2 40 ~ 15 15 2 40 4 7 -33 87 4 7 5 24 17 77 2 25 5 -1 179 12 5 12 20 15 15 12 20 13 45 60 25 85 13 45 15 0 120 -45 75 12 5 15 0 180 -5 175 23 10 23 25 0 15 15 23 25 1 0 120 -25 95 1 0 2 16 60 16 76 23 10 2 16 180 6 186 17 10 17 25 ' ~ 15 15 17 25 18 45 20 80 18 45 20 0 ~ 1201 -45 75 17 10 20 0,' 1'~~ -10 170 ........... 5 20 5 35 15 15 35 35 20 6 7 7 35 25 25 60 60 120' 0 -10 5 60 50 125 ANNULAR DISPOSAL CHRONOLOGY Redoubt Unit #1 FLOWBACK INJECTION PERIOD INJECTED FLUIDS AND VOLUMES (BBLS) VOLUMES (BBLS) COMMENT OIL TOTAL REPORTED LENGTH OF OIL BASED SEA SEA INJ AVERAGE BATCH FLOW START BATCH BEGIN END INJECTION BASED MUD WATER WATER FLUID INJECTION FLOW BACK DATE NUMBER TIME TIME (MINUTES) MUD CUM FLUSH CUM CUM RATE (BPM) BACK CUM 12/11/0C lA 17:25 19:1¢ 105 0 130 130 130 1.2 . . lB 19:20 20:1,". 55 165 165 130 295 3.(: i-c 20:15 '2-1:45 90 ..... 165 270 4~0 ..... 565 31(: 12/12/00 2A 7:40 7:551 15 165 40 440 605 2.7 .... 2B 7i55~ 9ii5 80 ~07 .... 372 :440 ..... 8i~ 2.6 ....... 2C ........ 9i-i~ -1-0::35 80 ............................................................................ 372 211 651 1023 2.6 12/12/00 3A 23:36 23:53 17 372 40 691 1063 2.4 12/13/00 3B 23:5,,! 0:47 54 145 517 691 1208 2.7 30 0:47 2:06 79 517 217 908 1425 2.7 First observation of seawater prior to initiating 4A injection. Wellhead representative contacted by rig re problem. Rig was told by Vetco Gray rep that "on the North Slope there was a history of water flowback from the annulus due to heat expansion and that some operators plugged off the fluted ports 12/13/00 4A 11:40 11:55 15 517 35 943 146(: 2.3 1 1 & monitored pressure buildup." Per the Vetco Gray rep "other North Slope operators simply allowed the water to flow back into the cellar". JMH COMMENT: Knowledge of North Slope annular disposal operations does not support this 4B 11:55 13:05 70 193 710 943 1653 2.8 comment. 40 13:05 14:25 80 710 200 1143 1853 2.5 Gray rep. 12/13/0(: '5A 18:00 18:20 20 710 40 1183 1893 2.C 5B 18:20 19:50' 90 231 941 1183 2124 2.6 5C 19:50 21:15 85 941 210 1393 2334 2.," 12/14/00 6A 7:1(: 7:30 20 941 33 1426 2367 1.7 ..................... 6'B ......................... ~'i'3'C .... 8:-45 ~5 ........ ~ 82 i'i"~ i~4~ ~5-4~ 2'.~4 6C 8:45 10:05 80 1123 198 1624 2747 2.5 12/14/00 7A 23:00 23:20 20 1123 35 1659 2782 1.8 12/15/00 7B 23:2C 0:35 75 194 1317 1659 2976 2.6 70 0:35 2:15 100 1317 199 1858 3175 2.0 12/15/00 8A 16:00 16:20 20 1317 37 1895 3212 1.9 8B 16:20 17:45 85 219 1536 1895 3431 2.6 80 17:45 19:25 100 1536 200 2095 3631 2.0 I ........... :1 .... .__1 I ...... I ......... ._1 ..... I. lF~~wback(5ga~~~ns~3~sec~nds)wasidentifiedwi~hin5minutes~fbeginni~ginjecti~n~~w~f~~wback 2'25 2' 40 15 ............... 1536 .................................. 2 2 ...................... irate ..m e..a s ..ur,em e n.t_s t. ,a..k..e n: ....................................................................................... Julie Heusser 2/11/01 Suumary prepared with data supplied by Forest Oil 1/15/01 ANNULAR DISPOSAL CHRONOLOGY Redoubt Unit #1 FLOWBACK INJECTION PERIOD INJECTED FLUIDS AND VOLUMES (BBLS) VOLUMES (BBLS) COMMENT OIL TOTAL REPORTED LENGTH OF OIL BASED SEA SEA INJ AVERAGE BATCH FLOW START BATCH BEGIN END INJECTION BASED MUD WATER WATER FLUID INJECTION FLOW BACK DATE NUMBER TIME TIME (MINUTES) MUD CUM FLUSH CUM CUM RATE (BPM) BACK CUM 9B 2:4(; 4:07 87 224 1760 2128 388~ 2.6 3:35 pm First note of "sheen" with returns. Six flowback rate measurements taken. ~i-Sc°sity Of fl(~wback reduces Witl~i~-43~min,-,'t%-'0~:'swappingt° seawater P~)st'flUsh. ~ flowback r~te-' 9c 4:07 5:24 77 1760 200 2328 408~ 2.6 3~ 39 measurements taken. Flowback (5 gallons/15 seconds) was identified within 5 minutes of beginning injection. "Sheen" seen 12/16/00 10A 12:05 12:20 15 1760 33 2361 4121 2.2 immediately. 1 flowback rate measured. w~t~i'~'45-m-Jn~tes-~f swapping to ~ii ~ase mUd~ chunks of"mUd'Sh°w up ~n the- fio~bac~'fl~-id~-N-i~'~ ...... 10B 12:20 13:45 85 220 1980 2361 4341 2.6 flowback rate measurements taken. W~('h~"~'~-~' ~f~'i~" {~'~'~te~ ~s~ f~-'~w~-f~ ~d ~iS~s~ty- ~'ars' t~- t~n~- "El~e~e~ 10c 13:45 15:0~ 75 1980 200 2561 4541 2.7 48 87 fiowback rate measurements taken. Flowback (5 gallons/20 seconds) was identified within 5 minutes of beginning injection. Two flowback 12/16/0C 11A 23:10 23:2~ 15 1980 34 2595 4575 2.~ rate measurements taken. ';~'~i~k~i'~'~'~-~iU i~-s--~e~' i-~'~'~i~i'~'~t-h-i-~-4~-'~i~ ~ ~f-~W~P~ ~'g-fr~m' s~-w~e~' p ~f'l~-s~'-t~ 'o~i ~-a~ 11B 23:25 1:00 95 245 2225 2595 482c 2.6 mud injection. Seven flowback rate measurements taken. .................................................................................................... W~t-h-i~ '26 ~-i'~e's-~-s~app-ing''t0''sea~te~'p~t'' fius~, 'fl0wback f~U'id ViSCoSity a-ppea~s't0-th~n~ Flowback rate doubles from 5 gals eve~ 10 seconds to 10 gallons within a 5 minute period. After cessation of injection, flowback returns continued for - another 36 minutes. Five flowback rate 12/17/00 11C 1:0C 2:16 76 2225 200 2795 502C 2.6 4~ 131 measurements taken. Flowback (5 gallons/35 seconds) with "sheen" was identified within 5 minutes of beginning injection. Flowback rate doubled within 10 minutes of beginning injection. Two flowback measurements taken. "Strong cement smell" was identified. JMH comment: THIS MAY BE AN INDICATION OF THE 12/17/00 12A 17:10 17:25 15 2225 35 2830 5055 2.3 QUALITY OF THE SURFACE CASING CEMENT. .................................................................................................................................................................................................. ~'i~'~'{' ~i~b-a~-~-~ u-r~.~ {.~--.t.~e-n.-~n~i.~-g..{-~--5-~a.i~o-~ .-p-~.-1-3, ~'~b ~as--tb '~-~'~-ilb~'s--~-~-55 12B 17:25 18:45 80 207 2432 2830 5262 2.6 seconds. least 20 minutes after cessation of injection. Five flowback measurements taken. Town notified rig 12C 18:45 20:0C 75 2432 200 3030 5462 2.7 46 177 to cease injection at 20:20 hm, 12/17/00. Julie Heusser 2/11/01 Suumary prepared with data supplied by Forest Oil 1/15/01 ANNULAR DISPOSAL CHRONOLOGY Redoubt Unit #1 FLOWBACK INJECTION PERIOD INJECTED FLUIDS AND VOLUMES (BBLS) VOLUMES (BBLS) COMMENT OIL TOTAL REPORTED LENGTH OF OIL BASED SEA SEA INJ AVERAGE BATCH FLOW START BATCH BEGIN END INJECTION BASED MUD WATER WATER FLUID INJECTION FLOW BACK DATE NUMBER TIME TIME (MINUTES) MUD CUM FLUSH CUM CUM RATE (BPM) BACK CUM Rig injection continues even though rig was previously notified to cease. Flowback returns (7 gals/minute increasing to 15 gals/minute) begin immediately upon beginning injection. Two flowback 12/18/0¢ 13A 5:2¢ 5:35 15 2432 32 3062 549z~ 2.1 measurements taken. Viscosity increases within 45 minutes of changing to mud injection from seawater. Eleven flowback 13B 5:3~ 6:35 60 154 2586 3062 564~ 2.6 measurements taken. FIowback returns continue for at least 45 minutes after cessation of injection. Eight flowback 13C 6:3,~ 7:25 50 2586 111 3173 5759 2.2 3z~ 211 measurements taken. First AOGCC notification of problem at 0810 hrs 12/18/00, Fluid injected since problem first identified but before measureable volumes of flowback. Volume of fluid injected since flowback began. Volume of fluid injected at the rig after directed by town to cease annular disposal Maximum volume of fluid injected after problem first identified 2239 bbls 2128 bbls 297 bbls 4334 bbls Julie Heusser 2/1 1/01 Suumary prepared with data supplied by Forest Oil 1/1 5/01 REDOUBT UNIT # 1 SUMMARY OF RETURNED FLUID OBSERVATIONS BATCH 9 12/16/01 BATCH 10 12/16/01 BATCH 11 12/16101 BATCH 12 12/17/01 BATCH 13 12118/01 VOLUME i TIME VOLUME ! TIME VOLUME i TIME VOLUME~ TIME VOLUME TIME (Gallons) I (Seconds) (Gallons) i (Seconds) (Gallons) i (Seconds) (Gallons) i (Seconds) (Gallons) (Seconds) 5] 30 5i 15 5! 20 5 35 7~ 60 5! 10 5! 19 51 20 51 13 15 60 5i 10 5~ 20 5i 15 5 20 15 60 5i 10 51 22 5i, 15 5: 17 15 60 51 20 5! 23 51 13 5:~ 15 15 60 51 20' 51i 15 5 10 5 20 5 32 5] 10 51 10 5i 15 51 20 5: 18 5i 30 51 10 51 15 5~ 23 5 15 5! 40 5~ 10 5i 10 5 20 5 15 I 51 12 5i 9 5 20 5~ 17 I 5! 10 5i 8.5 51 18 5 18 i 5~, 9 51 15; 5i 17 5 18 ! 5! 12 2.5i 6C 51 1~ 5 16 i i 5: 20 5; 18 ~ 5 19 ~ 5' 22 5 17 i 5 13 :i 5. 25 5 23 i 5J 15 ~ 5i 30 5 30 ~ 51 25 [ 5~ 35 5 35 i 5~ 65 [ 5 50 5. 30 i 51 150 ~ : 5= 30 ~ ! i 5 35 COLUMN TOTALS (gallons or seconds) 50 200 105i 508 67.5i 245.5 100~ 455 162 727 AVERAGE (gpsecond) ~ 0.25 " 0.21 i 0,27 0.22 0.22 COUNT 101 21i 141, 20 22 TOTAL RETURNS (bbls) ~ 38 ~ 48 I 44 46 34 '= Julie Heusser 2/11/01 Summary prepared with data supplied by Forest Oil 1/15/01 [Fwd: RD #2] Subject: [Fwd: RD #2] Date: Sat, 10 Feb 2001 11:02:50 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Julie Heusser <julie_heusser@admin.state.ak.us> Julie, FYI, here is a memo I sent to Paul and Rob at Forest regarding R#2. Tom Subject: RD #2 Date: Sat, 10 Feb 2001 11:01:46 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Paul White <pwhite@forestoil.com>, Rob Stinson <RDStinson@forestoil.com> Paul and Rob, I was in reviewing the RD #2 plan. When does it look like you will propose to spud?? I understand the platform is rather crowded with testing to commence on R#1. Based on preliminary review, I believe your requests/proposals to increase the surface hole size and depth will be granted. Please have a look at BJ's presentation for your surface cement job. It looks like the displacement volume for the 2nd stage is the same as the 1st. it would be helpful to have the stage tool depth stated in your program. From the BJ information I was able to determine that it was 2000'. It would also be helpful to have a larger (longer?) discussion on the casing and cementing operation. In other notes and the annular disposal application you talk of increased centralization and reciprocation to better achieve shoe isolation. I think a discussion of those points is important. There will be a couple of other points... ...If the 2nd stage cement doesn't get to surface, please notify us. It has been our practice on the slope to have an Inspector witness "top jobs". If such an operation were necessary, I presume it would be accomplished using a small diameter string run into the annulus to the TOC. Please confirm this. ...With regard to the LOT after drilling out. If l remember correctly, both the casing test and LOT test on R#1 were performed using a small volume test pump. I remember being surprised by pressure versus time on the plot. I have checked our guidelines and it is recommended to "pump at as Iow a rate as practical, but sufficient to overcome filtration losses". A minimum rate of .25 bpm is given. Last time I understand that the mud pumps were equipped with large liners that made Iow rate pumping difficult. Is it possible to use the cementing unit?? If not, how would you propose to be able to pump at say .25 to .5 bpm?? i look forward to your reply. Good luck on R#1. Tom Maunder I of 2 2/10/01 11:04 AM t Redoubt UnitADEval.xls Subject: Redoubt UnitADEval.xls Date: Fri, 09 Feb 2001 11:26:50 -0900 From: julie heusser~admin.state.ak.us To: Wendy D Mahan <wendy_mahan~admin.state.ak.us>, Tom Maunder <tom_maunder@admin.state.ak.us> Hello Wendy and Tom, Here's the Forest Oil info in spreadsheet format. Initial review of data suggests that there was a problem identified between the hours of 3:30 and 5:30 am on 12/13/00. It further suggests that injection went on for parts of two days after flowback was first observed. Furthermore, the information suggests that Forest rig personnel ignored directions from town and continued to dispose of fluids. If I were to be completely cynical, I could think that the rig personnel were operating under "do what we want to do and beg forgiveness later...". The records indicate 2128 bbls of fluid were injected over a 3 day period while flowback was occuring. We are on solid ground here if we choose to argue they should've ceased injection sometime during batch #9. Records indicate that the rig ignored the direction of town personnel to cease annular disposal and injected an additional 297 bbls of fluid. If we want to contend that the first observation of seawater constitued a problem that we should've been notified about, then the volume of fluid disposed contrary to our notification regulation was 4334 bbls. If we argue that notice was required at the first sign of measureable flowback, then the problem volume is approximately 2128 bbls - give or take a few. Tom and Wendy, please share your thoughts with me on this. At the moment it is very difficult for me to accept that the rig personnel were completely ignorant of the requirement to notify the AOGCC. Many Thanks Julie Name: Redoubt UnitADEval.xls I ~Redo'ubt UnitADEval.xls! Type: Microsoft Excel Worksheet (application/vnd.ms-excel) · Encoding: base64 Iofl 7/26/01 11:31 AM ANNULAR DISPOSAL CHRONOLOGY Redoubt Unit #1 ~ LENGTH OF! ;CUMULATIVE AVERAGE i INJECTION VOLUME (BBLS) VOLUME ~ BATCH BEGIN i INJECTIONi INJECTED DATE 'NUMBER! TIME ;END TIMEI (MINUTES) (BBLS) INJECTION RATE (BPM) REPORTED: CUMULATIVE FLOWBACK ~ FLOWBACK VOLUME i VOLUME (BBLS) i (BBLS) . . 12/11/00 1! 17:25i 21:45i 2601 565i 2.2 ~ O 12/12/00 2~ 7:40 10:35~, 1751 458', 2.6- 1023! 0 3i 23:36 2:06i 180 402! 2.2 142~ 14:25! 1651 428! 2.6 1853 21:15! 1951 481i 2.5i 2334; 0J 10:05! 1751 413i 2.4: 2747 Oi 2:15! 1951 428:~ 2.2: 31751 0i 19:251 205, 456 2.21 3631i O! 12/13/00 4 11:40 5i 18:00 12/14/00: 6i 7:10 ~ 7! 23:00 12/15/00 81 16:00 12/16/00: 9 2:25 5:24 179 457 2.6 4088; 38[ ! 10! 12:05 15:00 175; 453~: 2.6i 4541 481 11E 23:10 2:16~ 186; 479', 2.61 5020; 441 12/17/01~, 121 17:10 20:00 170i 442 2.6i 5462: 46 125 297i, 2.4! 5759'~ 34~ 12/18/00', 5:20 7:25 COMMENT 0~ 0 First observation of seawater at 0330 - 0530 hoursbefore 0 beginning to inject batch #4. 0 0 - 0 38 · 86 1~0? Rig notified by town to cease injection at 20:20 hours 176 12/17/00. i InjeCtion Continues even though rig was notified by town to cease injection. AOGCCverbally notified at ~ 0810 210i hours. Julie Heusser 2/9/01 Based on data provided by Forest Oil Company TIME (HOUR) 17 7 23 11 18 7 23 16 2 12 23 17 5 TIME (MINUTE) 25 40 36 40 0 10 0 0 25 5 10 10 20 END TIME (HOUR) 21 10 2 14 21 10 2 19 5 1,5 2 20 7 END TIME (MINUTE) 45 35 36 25 15 5 15 25 24 0 16 0 25 Re: Forest Oil RedoubtUnit #1 Annular Disposal Subject: Re: Forest Oil RedoubtUnit #1 Annular Disposal Date: Fri, 09 Feb 2001 10:09:12 -0900 From: Julie Heusser <julie_heusser~admin.state.ak.us> To: Wendy D Mahan <wendy_mahan~admin.state.ak.us> CC: Tom Maunder <tom_maunder~admin.state. ak.us>, Camille O Taylor <cammy_taylor@admin.state.ak.us>, Dan Seamount <dan_seamount~admin.state.ak.us> Thanks for responding Wendy, I haven't heard of this before either. I'm putting together a spreadsheet of volumes based on info provided by Forest Oil. I'll forward it to you. Thanks J Wendy D Mahan wrote: Hi Julie, I haven't heard of this before. Most of the problems related to annular disposal that I've been aware of are those of channeling due to poor cement, formation/shoe breakdown, excessive wear causing casing holes (KR U), flow prior to setting surface casing, and diesel fumes. It wouM be nice to know the extent of this problem and volumes associated with it. Thanks, Wendy ..... Original Message ..... From: Julie Heusser <julie_heusser~admin.state. ak. us> Date: Friday, February 9, 2001 12:31 pm Subject: Forest Oil RedoubtUnit #1 Annular Disposal Good Morning Wendy and Tom, I am in the process of reviewing the info submitted by Forest Oil surrounding the annular disposal problems on Osprey Platform well Redoubt Unit #1. What caught my eye was the Grind/Inject report from Don Jones, Forest Oil drilling foreman where he states: "I contacted Vetco Gray rep. Ves Cash about our problem. Ves shared comparable sitations on the slope where during injection (and/or) drilling operations there was a history of water flow back from the conductor and 13-3/8" annulus due to heat explansion. Some operators plugged off theflutedports and monitored the pressure buiMup and others simply allowed the water to flow back into the cellar." 1 of 2 7/26/01 11:31 AM Re: Forest Oil RedoubtUnit #1 Annular Disposal ,., > > Wendy/Tom - are either ofyou aware of the situation described above? > > Many Thanks > > dulie 2 of 2 7/26/01 11:31 AM Forest Oil RedoubtUnit #1 Annular Disposal Subject: Forest Oil RedoubtUnit #1 Annular Disposal Date: Fri, 09 Feb 2001 09:31:16 -0900 From: Julie Heusser <julie_heusser~admin.state.ak.us> To: Wendy D Mahan <wendy_mahan~admin.state.ak.us>, Tom Maunder <tom_maunder~admin.state.ak.us> CC: Camille O Taylor <cammy_taylor~admin.state.ak.us>, Dan Seamount <dan_seamount~admin.state.ak.us> Good Morning Wendy and Tom, I am in the process of reviewing the info submitted by Forest Oil surrounding the annular disposal problems on Osprey Platform well Redoubt Unit #1. What caught my eye was the Grind/Inject report from Don Jones, Forest OI1 drilling foreman where he states: "I contacted Vetco Gray rep. Ves Cash about our problem. Ves shared comparable sitations on the slope where during injection (and/or) drilling operations there was a history of water flow back from the conductor and 13-3/8" annulus due to heat explansion. Some operators plugged off the fluted ports and monitored the pressure buildup and others simply allowed the water to flow back into the cellar." Wendy/Tom - are either of you aware of the situation described above? Many Thanks Julie Iofl 7/26/01 11:31 AM " 1755' S.D .and depart. .. March 23, 2001 0815 ^rdve at off~'e Talk with John Spautding regarding Nordic 3 BOP test... ! did not receive any notices.., he plans to go out and talk with them.., also will be goln9 over to look at the valve from DS 7-8. , 0835 Look at 404's UIC KRU... 1L-10... (190-035)... (300-320)... workover of injection well.., need to check the sundry KRU... 1H-01._ (193-006)... (300-318)... production well workover.., difficulty killing and keeping dead... SI several times.., end of February timing PBU... 02-01B... (197-140)... no sundry.., install BP for GSO... reduced gas from 27 MM to 2MM with oil increase PBU... 15-35... (194-088)... no sundry.., add perfs.., no oil to 760 bpd Pt. Mac... P2-13... (197-060)... no sundry.., add perfs.., increaSed oil and water 0915 John called back and they checked the message and there was a page from Nordic... he will look in to what pagers , might be available 0930 Call Paul White and inquire if they had received the fax ! sent over.., confirmation did not indicate... Talk to Rob Stinson... did annulus diagnosis on RU #1... took about 25 bbls to fill annulus... 1/2 bpm to fill and increased to 1 bpm and 120 psi, pressure dropped to 50 to 60 psi RU #2 injection procedure.., did injectivity test as designed.., up to 3 bpm at about 720 psi 1020 Call from Dan Kara... MP C-12A... had been stuck and couldn't disconnect.., cut just above the connector.., got free... POOH with coil and sent unit to yard to spool new coil.., plan to set BP... and rethink " 1310 Look at PPCo 403 for Nigliq #1... (201.036)... (301-062)... covers plan to plug back to sidetrack.., had discussed with Scott Reynolds in advance of the operation and given verbal approval,,., pass on for processing,. 1325 'Look at BP 403 for Trailblazer pd A No. 1... (201-013)... (301-063)... proposal is to increase the ultimate depth due to the formation tops coming in deeper.,, had discussed with Fred Johnson on March 19.., pass on for approval , , 1400 Return with Alex... meet in hearing room. .... r 1945 ,, February xx, 2001 Mr. Paul White Drilling Manager Forest Oil Corporation 310 K Street Anchorage, AK 99501 Dear Mr. White: The Commission has received an Application for Sundry Approvals dated 2/2/01 requesting authorization to allow annular disposal of drilling waste in the RU #2 well. We cannot further process the request until the following information is provided: cementing records and cement quality log or formation integrity test records, including the downhole pressure obtained (20 AAC 25.080(8)(A)(B), and (10). Additionally, the Commission will require sufficient demonstration that the RU # 1 well cannot act as a conduit for wastes to surface prior to granting approval for annular disposal in the RU #2 well. Once this additional information is received, we will continue processing the Application for Sundry approvals. Please contact Tom Maunder if you have any additional questions. Sincerely, Commissioner STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate:" Change approved program: Puli tubing: Variance: Perforatei Other: X Annular Disposal. 2. Name of Operator' 5. Type of well: 6. Datum elevatiOn (DF or KB) Forest Oil Corporation. Development: 90' MSL feet 3. Address Exploratory: X 7. Unit or Property name 310 K Street, Suite 700 Stratigraphic: Redoubt Unit Anchorage, Alaska 99501 Service: 4. Location of well at surface 8. Well number 1918' FSL, 320' FEL, Sec. 14, T07N, R14W, SM RU #2 At top of productive interval 9. Permit number 2306' FNL, 755' FVVL, Sec. 19, T07N, R13W, SM ~ (,~' ~ - ~ '~ \ At effective depth 10. APl number At total depth 11. Field/Pool Redoubt Shoal Oil Field 2475' FSL, 1505' FWL, Sec. 19, T07N, R13W, SM R~doubt Shoal 12. Present well condition summary Total depth: measured Plugs (measured) true vertical Effective depth: measured Junk (measured) true vertical Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate Production (Liner) RECEIVED Perforation depth: measured , t~ue ~.~o~ ~'~-:9 0 2 2001 Tubing (size, grade, and measured depth) Alaska 0il & Gas Cons. Com~ Packers and' SSSV (type and measured depth) 131Attachements. Description sum'mary of proposal: X Detailed operations program: BOp sketch: i 4. EStimated date for commencing operation 15. Status of well classification as: Feb. 15, 2001 16. If Proposal well verbally approved: Oil: X Gas: , . Suspended: . Name of ~er Date approved Service: 17. I hereby ~ true and correct to the best of my knowledge. Signed: ~--~,,~ ~,,a ¥~,,.-~--~ Title: Drilling,Manager. Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test Location clearance I ~ ~ "'~.c~ Mechanical Integrity Test . Subsequent form required~10-. ~ (3~"~,~,~,'~ ~,q: O~3~t' ~ ApproVed by order of the Commissioner .? r:',~...~:. ', ',:...". ..... Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE FOREST OIL CORPORATION OSPREY PLATFORM REDOUBT SHOAL #2 (RU #2) RECEIVED 2001 20 AAC 25.080(b)(1)--Annulus to be used for disposal. Oil & Gas e, ms. Forest Oil Corporation proposes to dispose of drilling waste through the 13 3/8 inch by9 5/8 inch annulus in the RU #2 well. The setting depth of the 13 3/8 inch surface casing will be approximately 2906 feet TVD (3200' MD) and the setting depth of the 9 5/8 inch casing will be approximately 7525 feet TVD (9000' MD). A well casing diagram and deviation profile are attached. 20 AAC 25.080(b)(2)--Depth to base of freshwater aquifers and'permafrost, if present. The total dissolved solids (TDS) content of formation waters in the recently completed RU gl well generally ranges between 3,000 mg/1 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/1, but occasionally drops below 10,000 mg/1 through some intervals. Forest Oil believes the lower salinity reading are due to lithology changes and clay content, and does not necessarily indicate freshwater. The TDS content in the RU gl well generally dovetails with the Redoubt Shoal State 29690 gl well, where salinity exceeds 10,000 mg/1 below 2400 feet TVD. The TDS pr°file in both wells is based upon petrophysical analysis of log data using an EPA approved method for determining salinity. The RU # 1 well logs is 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 #2 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 #2 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 2906 feet TVD, Forest Oil requests commission authorization.under 20 AAC 25.080(e)(1) to dispose of drilling wastes into any freshwater that may exist in'the RU #2 well below this depth. Formation water in the RU #2 well isnot 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)wStratigraphic Description. The intraVel proposed for annular disposal in the RU #2 well is between 2906 feet and 7525 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 #2 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 #2 annulus, and should provide adequate protection for any freshwater resource that may exist al:love the disposal zone. 20 AAC 25.080(b)(4)--Adjacent wells Wells within one-quarter mile of the RU #2 well include: Redoubt Shoal state 29690 #1 and #2 wells Redoubt Bay Unit #1 well There are no publicly recorded water wells within one mile of the RU #2 well. 20AAC 25.080(b)(5)--Types and volume of waste Drilling waste proposed for annular disposal in the RU #1 well will be limited to that allowed under 20 AAC 25.080(h)(1) & (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 #2 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, domestic waste and Produced waters will also be disposed. Forest Oil may also reqUests approval to use the RU #2 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). For long-term disposal, Forest Oil plans to drill a dediCated UIC Class II injection well should commercial production be pursued. RECEIVED 2001 Alaska Oil & Gas Cons. Commi~on Anchorage 20 AAC 25.080(b)(6) Other wastes No other waste other than wastes defined under 20 AAC 25.080(h)(1) & (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 2397.45 psi. This is based upon an estimated formation fracture pressure gradient of about .75 psi/foot and a setting depth for surface casing of about 2906 feet, plus a 10% error margin. AP = F G x D + 10% (.75 psi/ft)2906 ft + .1((.75 psi/ft)2906 fi)= 2397.45 psi. 20 AAC 25.080(b)(8)--Cementing details Cementing records and the results of the formation integrity test on the surface casing shoe will be presented to the commission after they are obtained. Because of the recent broach in the RU #1 well, Forest Oil is taking special precaution to ensure a 'good cement job with the RU #2 well. The size of the surface hole will be increased to 18½ inches and centralizers will be used on the 13 3/8 inch surface casing. The casing will be cemented in place in two stages using a cement stage collar at about 2,000 feet. To aid in cement displacement, the casing will be reciprocated during cementing operations. Forest Oil will also conduct remedial work in the RU #1 well to seal'the annulus with cement so the well cannot serve as a conduit for fluids disposed in the RU #2 well. Forest Oil will not proceed with disposal operations in the RU #2 well until the RU #1 well is repaired. The proposed.setting depth of the RU #2 surface caSing may be above the base of freshwater, as defined under commission regulations. Although TDS content in the RU tr#1 well generally exceeds 10,000 mg/1 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 2906 feet TVD in the RU #2 well, Forest Oil requests that the commission issue a finding under 20 AAC 5.080(e)(1)that any freshwater encountered below this depth is likely to have a TDS content'greater 3,000 mg/1, 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. RECEIVED 02 2001 Aia~ka Oil & Gas Cons. Commisskm Anchorage 20 AAC 25.080(b)(9)--Casing strength Casing Joint Strength Body Strength Burst Collapse K lbs K lbs Psi Psi 13 3/8" 68# L-80 BTC 1545 1556 5050 2260 9 5/8' 47# L-80 BTC 1122 1086 6870 4760 20 AAC 25.08(b)(10)~Downhole pressure The downhole pressure obtained during the formation integrity test will be presented to the commission once it is obtained. 20 AAC 25.080(b)(11)mHydrocarbon zones No significant hydrocarbon zones are anticipated above the setting depth of the 9 5/8 inch casing at 5987 feet TVD. 20 AAC 25.080(b)(12)--Duration Disposal of' drilling wastes generated from the drilling of the RU #1 well will not exceed 90 days in duration. Forest Oil will likely use the RU #2 well annulus for disposal of drilling wastes from other wells on the Osprey platform, but does not anticipate at this time any need to exceed the 35,000 barrel and one year disposal limitations under 20 AAC 25.080(d). 20 AAC 25.080(b)(13)--Prior disposal The RU #2 well is the second 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 #2 will be used to dispose of drilling wastes generated during its drilling, as well as drilling wastes from other wells on the Osprey Platform. 20 AAC 25.080(b)(15)MDisposal Limitations Forest Oil does not anticipate at this time any need to exceed the 35,000 barrel and one year disposal limitations under 20 AAC 25.080(d). · RECEIVED 02 2001 Alaska Oil & Gas Cons. Com~ ~chorage RU #2 Casing Design 36" Piles 13 3/8" 68~, L-80 B 18 1/2" Hole 9 5/8' 47#, L-80 BTC 12 1/4" Hole 3 1/2' 9.3 #, L-80 Tubing 200' MD, 200' TVD m3200' D, 2906'TV 9000' MD, 7525; TVD 7-5/8' 29.7#, L-80 Hydril 521 8 112" Hole 14,104' MD, 11,591' TVD 5-1/2' 17#, L-80 Hydril 521 6 3/4' Hole 15,593' MD, 12,776' TVD RECEIVED , ,_= 02 2001, ~chomge ' · -.': 02 2001 kla~a Oil & Gas Cam. Comm~~ Anchorage . ~~Redoubf U ~ 23 2~ ~ 19 R~do~6~ U ~2 , · 5 s. .... O~ , ~W-~---~ .... 08N 15W ~"~ .---~ /.. [___ ~ ~ ~ · , m ......... ~7~-' 14 ~-~W ...... ~ , o~ ~~ ...... ~-,-~-~ ...... Unit . . WELL DGT^I/.S ~u~e 200625.0D 60'41'43.'/52N COMPANY I~'TAIL,S Cook ln~ W~"n~ I~e~: Ruin l]a~d SURVEY' PRO(]RAM De~b.,Fm Dep~Tu Smveytl'b,n .Tuvl ~X00 1~593.1~ plme~l: Redcub!. L'nill{2 Wp2 V MWD 9,~]I.LPATI I DETAILS Reduubt a2 VmlcalSectlouOdlb: Slot- (0.00,0.00) Vc~kal S~don/m~k~ 12~.05' Del.fi Rcfmenc~ Pbn: RedoubtUn~//2 1250' 2500- 3750- 500~ 625~ 750ff 875~ 1000~ 1125~ 1250~ 13750- 1000 7000 10000 I1000 2000 3000 400O 5000 60O0 8000 9000 12000 West(0/Eas~+) [2000ft/~] 3000 4000 5000 6000 -1000 .0 1000 2000 7000 8000 9000 I0000 1000 1000 '~0 "~0 ',4[0o g! ~oooo ~ * % ~ ' Redoubt ~it ~2 Wp2 --1000 --2000 --3000 --4000 --5000 =6000 13000 ~4000 Redoubt HemlockTarget 15000 · RedoubtgRtit#2 ~ 0 1250 2500 3750 5000 6250 7500 8750 10000 Vertical Section at 125.05° [2500fi/in] COPY DR, F T O'NLY SHC'rlON I~(r^ll$ .~ ,MD lm A~ TVI) ~.~ 0.~ ~ ~ 0.~ 0.~ 0,~ 0.~ 0.~ 5~.~ 0.~ ~ 5~ 0.~ 0.~ 0.~ 0,~ 0.~ _ ~.~ ~.~~.~ ~.~ ~.5l 6.4~I.~1~.05 ~.~5 11~.~1~ 1~ 1~.~ l~.~~.~ H9~,32-51.~ %.65 g~ 0,~ ~.~ 141~ 37.21 I~.~ llS}l.~ 1~3.1~ 37.21 I~.~ 1~ 4~71 67~ 0.~ 0.~ ~ 15593.1X 37.21 12{.~1~19 ~.~ R E T OIL C 0 R P 0 RAT ~c./j,,../,,-, '"': v'". oc:/%,.;/,-,-,.: ,'.,..;,,',/ -- x.:,~'-,~'x,'f.x, · (/xf>")..,.;.~'-.v6'(/ (--~,.,-) February 1, 2001 I O N Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Attention: Commissioner Julie Heusser Re: Redoubt Unit (RU) #2 well, annular disposal Dear Commissioner Heusser: Forest Oil, Inc. request approval under 20 AAC 25.080 for the annular disposal of drilling waste in the RU #2 well. Enclosed is an Application for Sundry Approvals (Form 10-403) with supporting information as required by regulation. Forest Oil will submit cementing records and the results of the formation integrity test on the surface casing shoe after they are obtained. The TDS profile from the RU #1 well indicates that salinity below the proposed setting depth of the RU #2 surface casing shoe (2906 feet TVD) is generally above 10,000 mg/1, 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 2906 feet TVD in the RU #2 well, Forest Oil requests that the commission issue a finding under 20 AAC 5.080(e)(1) that any freshwater encountered below this depth is likely to have a TDS content greater 3,000 mg/1, 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 question you or your staff may have. Thank you. Paul White Drilling Manager Attachment bcc: Art Saltmarsh Rob Jeffery Rob Stenson John Amundsen David Johnston- Hoefler Consulting File G:\ 1307 - Forest Oil\ 1307-009\ 1307-009-100\RU#2 Annul ar Disposal.doc ALASKA OIL AND GAS CONSERYA ION COP IISSION Paul White Drilling Manager Forest Oil Corporation 310 K Street, Ste 700 Anchorage, AK 99501 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Redoubt Unit #2 Forest Oil Corporation Permit No: 201-031 Sur. Loc. 1918'FSL, 320'FEL, Sec. 14, T7N, R14W, SM Btmhole Loc. 2475'FSL, 1505'FWL, Sec. 19, T7N, R13W, SM Dear Mr. White: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Approval of your annular disposal application is subject to obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) on this well and the possible impacts of the surface casing and cement condition of the Redoubt Unit #1. Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10-403 prior to the approval of disposal operations. Your request for an exception to 20 AAC 25.035 (c) (1) (B) to drill 18-5/8" hole with a 16" diverter line is granted. Your plan to test blowout prevention equipment (BOPE) to 3000 psi is approved for the 12- 1/4" hole section only. BOPE test pressure for the deeper hole sections remains at 5000 psi until the Commission has had an opportunity to examine the formation pressure information obtained in RU #1 and expressly reduces the required test pressure. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the diverter function test and BOPE tests must be given so that a representative of the Commission may witness or waive witnessing the tests. In addition to the BOPE test notices, you are required to provide the same notice prior to running the surface casing so an Inspector may witness those subsequent operations if desired. Mr. Paul White Forest Oil Corp. 2 201-031 February 16, 2001 All notices required by this permit may be given by contacting the Commission Petroleum Engineer at 793-1250 during business hours or the North Slope Field Inspector's pager at 659-3607 anytime. Should you encounter any problems that may require deviating from the operations described in your application, contact the Commission Petroleum Engineer or North Slope Field Inspector immediately. ~om~isT~i~neeTOUnt, Jr. BY ORDER OF THE COMMISSION DATED this /l~ -~' day of February, 2001 dlf/Enclosures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. FOR E .ST OIL C o R P O RAT I 0 N January 15, 2001 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill (Form 10-401) Redoubt Unit #2 Enclosed is the Application for the Permit to Drill the Redoubt Unit #2 exploration well from Forest Oil's Osprey Platform. This well is planned to penetrate and Drill Stem Test the Hemlock formation near the top of structure. The well will be drilled using water based mud to the 9 5/8" intermediate casing point, during which the cuttings will be discharged overboard under our NPDES discharge permit #AKG285024. We will change mud systems at this point to an oil based system. We are requesting in a separate 10-403 Sundry Notice to use the 9 5/8" x 13 3/8" annulus for cuttings disposal while using oil base mud. We will have the grind and inject equipment on the platform to perform this task. In addition, we are requesting a waiver to 20 AAC 25.035 (c) (1) (B), as it pertains to the required hole size, while drilling with a diverter. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forest Oil Corporation- Alaska Division RECEIVED JAN 2 ?001 Alaska Oil 8, Gas Cons. Commission Anchorage STATE OF ALASKA .'' ALASKA OiL AND GAS CONSERVATION tt.,OMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: X Redrill: I 1 b. Type of well Exploratory: x Stratigraphic Test: Development Oil: Re-Entry: Deepen:I Service: Developement Gas: Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Forest Oil Corporation 90' MSL Redoubt Shoal Oil Field 3. Address 310 K Street, Suite 700 6. Property Designation Redoubt Shoal Anchorage, Alaska 99501 381203 (Surface) 374002 (TD) 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o A^C 25.025) 1918' FSL, 320' FEL, Section 14, T07N, R14W, SM Redoubt Unit At top of productive interval 8. Well number Type: Statewide Oil and Gas Bond 2306' FNL, 755' FVVL, Section 19, T07N, R13W, SM Redoubt Unit #2 RLB0001940 At total depth 9. Approximate spud date Amount: 2475' FSL, 1505' FVVL, Section 19, T07N, R13W, SM 15-Feb-01 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 7623 feet 2140 feet 23,526 15,593' MD / 12,776' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o ^AC 25.035 (e)(2)) Kickoff depth: 500' feet Maximum hole angle: 38 Maximum surface 1491 psig At total depth (TVD) 5558 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Driven 36" Welded 200' Surf Surf 200' 200' n/a 18 1/2" 13 3/8" 68 # L-80 BTC 3,200' Surf Surf 3,200' 2,906' 5710 cu It 12 1/4" 9 5/8" 47# L-80 BTC 9,000' Surf Surf 9,000' 7,525' 645 cuft 8 1/2" 7 5/8" 29.7# L-80 Hyd 521 5,304' 8,800' 7,366' 14,104' 11,591' 171 cuft 6 3/4" 5 1/2" 17# L-80 Hyd 521 1,689' 13,904' 11,430' 15,593' 12,776' 191 cuft 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor RECEIVED Surface Intermediate Production JAN g 4 2 O 01 Liner Perforation depth: measured Alaska 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: Drilling program: Drilling~fluid program: X Time vs. depth plot: X Refraction analysis: Seabed report: 20 AAC 25.050 requirements: X 21. I herby ~;e~ify that the foregoing is true and correct to the best of my knowledge: Signed: ~'~ Paul White Title: Drilling Manager Date: Commission Use Only Permit Number I APl number I Approval date I See cover letter ~/'" ~ ..~1 50- "~ ~ '2~ -... 2Z2.~'0l- ~) ¢;~ "'/~2 '"~.-~/ for other requirements Conditions of approval Samples required: [V.J Yes [ ] No Mud Icg required: ~ Yes [ ] No Hydrogen sulfide measures [ ]Yes ~,No Directional survey required [¢l~'Yes [ ] No '~O(~¢-~, Required working pressure for BOPE []2M; ~ []5M; []10M; []15M S<:~O Other: OI~IOIN/:\I.. ~:.:l(..,t.,'.~ . by order of Approved by [_.3 '[;.~ylor Seai'l'lou,l, Commissioner the Commission Date: Form 10-401 Rev. 12-1-85 Submit in triplicate Attachments o 5. 6. 7. 8. 9. 10. 11. 12. 13. Waiver Requests Outline Procedure Well schematic Unit Boundary Plat w/Proposed Well Path Drilling Fluids Program Pressure Information Casing Design Cement Calculations Directional Information Well Head Schematic Nabors BOP schematic Nabors BOP equipment list Nabors Drilling Fluid System Description RECEIVED J/~N B 4 2001 Alaska Oil & Gas Cons. Commission Anchorage Request for Hole Size / Diverter Outlet Waiver Forest Oil requests a waiver to 20 AAC 25.035 (c) (1) (B) as it pertains to the drilling of Redoubt Unit #2. Specifically, we request to drill 18 1/2' hole with a 16" diverter outlet. Based on the accompanying geologic information, we believe that there is little or no risk of encountering any gas while drilling the surface hole on this well. In addition to increasing the diverter outlet size from 10" to 16", we have explored various options to comply with this provision and all options have significant impact to the operational and financial aspects of this well. Attempting to run 13 3/8" surface casing in 16" hole would be very tight and we would have a risk of sticking the surface pipe. In addition, we feel that the cement integrity would be compromised with this very tight annular space as compared to the desired 18 lA' hole. If we elected to change out surface casing to the next available smaller size we would have to change the casing and hole sizes all the way to the well's planned TD, not to mention the difficulties in locating odd sized drilling tools and tubulars. Drilling a pilot hole and opening it up to 18 1/2' hole presents difficulties as well. Opening up the surface hole would take approximately as long as drilling the pilot hole, thus extending the time on the well by two to three days. Also, the drilling is extremely rough while opening up the surface hole, thus imparting unnecessary wear and tear on the surface equipment. RECEIVED JAN 2 4 ~001 Alaska Oil & Gas Cons, Commission Anchorage . 2. 3. 4. o . 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Redoubt Unit #2 OUTLINE PROCEDURE Rig-up Rig on Osprey Leg//3, Slot ~2. Install weld-on starting head on 36" Pile. Mix Spud Mud. Nipple up 24" low pressure riser to bell nipple with 21 ¼ ' 2M diverter. Diverter will have a 16" outlet. Function test diverter system. Notify AOGCC 24 hours prior to test. Directionally drill 18 ¥~" hole to 3,200' MD, 2,906' TVD. Note: Annular velocity and mud viscosity will be important for proper hole cleaning in the 36" pile. Discharge cuttings overboard. Condition hole to run casing. Run and cement 13 3/8" surface casing from 3,200' MD to Surface. Hang 13 3/8" casing in the 20" landing ring. A two-stage cement job will be performed with a DV collar. Discharge cement returns overboard through platform pulltube. Note: If there are no returns at surface, perform top-job. Nipple down diverter, diverter spool and 24" riser. Nipple up Vetco-Gray 13 5/8" 5M Multi-bowl wellhead assembly on the 13 3/8". Nipple up 13 5/8" 5M high pressure riser assembly and Nabors 13 5/8" 5M BOPE. Test wellhead and BOPE to 3,000 psi Notify AOGCC 24 hours prior to test. RIH. Test casing to 3,000 psi. Drill out cement and float equipment. After drilling 20', but no more than 50' of new formation, perform Leak off Test. Directionally drill 12 ¼" hole to 9,000 MD, 7,525' TVD. Discharge cuttings overboard through platform pulltube. Condition hole for casing. Run wireline logs: Quad Combo from 9,000' MD to base of 36" Pile. Run and cement 9 5/8" intermediate casing from 9,000' MD to Surface. Planned top of cement will be 7,500' MD. Hang casing with 9 5/8" mandrel hanger in wellhead. Displace cement plug with Oil Base Mud system. Back off 9 5/8" landing joint. Test 9 5/8" packoff. RIH. Test casing to 3,000 psi. Drill out cement and float equipment. RECEIVED JAN 2 Alaska Oil & Gas Cons. Commission Anchorage After drilling 20', but no more than 50' of new formation, perform Formation Integrity Test to 10.5 ppg EMW. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. 35. 36. 37. 38. 39. 40. 41. 42. Directionally drill 8 %" hole to 14,104'MD / 11,591' TVD or until the top of the Hemlock formation is encountered. Cuttings will be slurried and disposed of in the annulus. Run wireline logs: Quad Combo, UBI Condition hole, Run and cement 7 5/8" liner fi.om 8,800' MD to 14,104' MD. Planned top of cement will be 12,604' MD. Pick up 3 a/2" drill pipe / BHA and run in hole. Clean out liner and test lap to 4000 psi. Drill out cement and float equipment. After drilling 20', but no more than 50' of new formation, perform Formation Integrity Test to 10.5 ppg EMW. Directionally drill 6 3A' hole to TD at 15,593'MD / 12,776' TVD. Cuttings will be slurried and disposed of in the annulus. We anticipate cutting three 30' cores. Condition hole and run wireline logs: Quad Combo, FMI and RFT logs across the 6 3A" hole. Condition hole for liner. Run and cement 5 1/5' liner from 13,904' to TD. Note: Liner will have a high torque thread and the liner will be reciprocated until cement hits the shoe, then it will be rotated and reciprocated as long as possible or until the plug bumps, setting the liner hanger. The entire length of 5 ah" liner will be cemented. RIH with a tapered clean out assembly. Clean out liner and test lap to 4000 psi. Change hole over to Inlet water. Run USIT and RST logs across the 5 aA" liner Perform DST on Hemlock. Run 3 ah' completion with ESP. Nipple up production tree. RECEIVED JP, N 2 4 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage RU #2 Casing Design 36" Piles 13 3/8" 68~, L-80 B 18 1/2" Hole 9 5/8" 47#, L-80 BTC 12 1/4" Hole 3 1/2" 9.3 #, L-80 Tubing ~, 200' MD, 200' TVD 3200' MD, 2906' TVD 9000' MD, 7525' TVD 7-5/8" 29.7#, L-80 Hydril 521 8 1/2" Hole 14,104' MD, 11,591' TVD 5-1/2" 17#, L-80 Hydril 521 6 3/4" Hole 15,593' MD, 12,776' TVD RECEIVED JAN 2 4 ~001 Alaska Oil & Gas Cons. Commission Anchorage ~ yU 1 R~;doz6bf U ~2 JA[ g 4 ~001 ~ ' ' ~laska Oil & G as Cons. Commission ~ ~W ...... ~, . ,. ............ Redoubt U~t//2 DRILLING FLUID PROGRAM RECEIVED JAN 2, 4 2001 AJaska Oit & Gas Cons. Commission Anchorage Interval Summary WBM Forest Oil Corporation Redoubt Shoal Unit #2 Mixing Procedure J[~E CEj~E~) · Fill rig pits with drill water · Add 0.25 ppb Soda Ash to reduce hardmess J/IN ,~ z1 ~001 · Add 22 - 25 ppb M-I Gel and let shear and hydrate through gun lines. Alaska Oil 8, Gas Cons. Commission · Adjust pH to 9.0 with Caustic Soda as needed. Anchorage · At time of spud, adjust rheology with Gelex additions as needed. Mixing Procedure · Add 45 barrels of spud mud to slugging pit. Mix blend of LCM products & spot across theft zone. M-I L.L.C. 721 W. 1 st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729, IFE Interval Summary, Cont. Forest Oil Corporation Redoubt Shoal Unit//2 0 to 3,200' md - 18 112" Hole - Set 13 318" Casing · ROP, GPM · Estimated ROP for this interval is 40 fi/hr. · Estimated flowrate of this interval is 600 GPM. · Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. · Bit bailing · Drilling Detergent may be used t° reduce the possibility of bit and/or BHA bailing. · Hole cleaning · High viscosity Gel/Gelex sweeps may be needed to ensure cleaning of gravel zones just below the 36" drive pipe. · NOTE: Due to a larger diameter hole and a deeper casing depth than RU #1, a higher viscosity fluid will need to be maintained longer to insure sufficient hole cleaning. · Lost Circulation · Seepage losses may be controled with moderate additions of M-I Seal Fine & Medium · Severe lost circulation should be handled with LCM pills such as the one listed for this inter- val. · Casing running fluid properties · The mud should be conditioned prior to POH to run casing. Moderate or reduce yield point and progressive gel strengths in order to reduce surge pressure whille running casing. A small addition of Polypac UL should help lower the fluid loss (10- 12 ce's) and tighten the wall cake prior to nmning casing. · The IFE Mud Engineer will communicate daily with the In Office IFE Coordinator. · VOLUME USAGE · Estimated fluid volume required for this interval is 4750 barrels. RECEIVED J~N 2 4 ~001 Alaska Oil & Gas Cons. Commission Anchorage M-I L.L.¢. 721 W. 1 st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 IFE Interval Summary J A N g A ~oOrlest Oil Corporation INBM ^laska Oil & Gas Cons. C~s~t Shoal Unit #2 1 II .......fl- 10 2O 10-15 PPB 35 bbls i 5 10 10 5 ~ M-I L.L.C. 721 W. 1 st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 IFE Interval Summary,.Cont. Forest Oil Corporation Redoubt Shoal Unit #2 3,200 to 9,000' md - 12 114" Hole - Set 9 5~8" Casing · ROP, GPM · Estimated ROP for this interval is 30 fi/hr. · Estimated flowrate for this interval is 650 GPM. · Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. · Bit Bailing · Drilling Detergent may be used to reduce the possibility of bit and/or BHA bailing. · Lost Circulation · Seepage losses may be controled with moderate additions of M-I Seal Fine & Medium · Severe lost circulation should be handled with LCM pills such as the one listed for this interval. · Coal Beds · Sloughing/nmning coal should be treated by increasing the concentration of Soltex in the mud system to 2- 4 ppb depending on the severity of the problem. · For severe Coal sloughing, a concentrated pill consisting of 15 - 20 ppb Soltex may be spotted across the coal bed prior to POH for a trip. A slight mount of pressure (equal to the annular pressure loss) may be applied to the pill to squeeze it into the coal bed. · Casing running fluid properties · The mud should be conditioned prior to POH to run casing. Moderate or reduce yield point and progressive gel strengths in order to reduce surge pressure whille running casing. Additions of Polypac UL should'help lower the fluid loss (10- 12 cc's) and tighten the wall cake prior to running casing. · The IFE Mud Engineer will communicate daily with the In Office IFE Coordinator. · VOLUME USAGE · Estimated fluid volume required for this interval is 3950 barrels. RECEIVED J/~N ~ 4 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage M-I L.L.C. 721 W. 1 st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 IFE Interval Summary' OBM Forest Oil Corporation Redoubt Shoal Unit #2 Mixing Procedure · Premix and store 10.3 ppg Cacl2 Brine (0.914 bbl H20, 113.4 lbs CaC12) · Place Mapco 200 in a clean mixing tank · Add IMG 400 and lime slowly through hopper. Let shear for 30 minutes. · Add primary emulsifier, Versacoat. · Blend and shear for a minimum of 30 minutes. · Add CaC12 Brine. · Blend and shear for a minimum of 30 minutes. · Add Versawet, check theology, add Versamod or VersaHRP as needed. RECEIVED JAN Alaska Oil & Gas Cons. Commission Anchorage M-I L.L.C. 721 W. I st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 IFE Interval Summary 0 RECEIVED JAN ~ <~ 2001 Forest Oil Corporation I~ ~Ia 0il & Gas Cons. ¢omR~ubt Shoal Unit #2 Anchorage I Ii Mixing Procedure · Place 35 bbls oil mud in slugging pit. Add blend of lost circulation material. Spot across theft zone. Mixing Procedure · Place 35 bbls oil mud in slugging pit. Add 15 - 20 ppb Ventrol 401. Spot across theit zone and apply squeeze pressure not greater than annular pressure loss. Mixing Procedure · Place 30 bbls oil mud in slugging pit. Add 5 bbls base oil, 5 gallons Versacoat and 2 gallons Versawet. Add barite for a mud weight of 3 ppg above current weight. Reciprocate and rotate while pumping pill. Do not stop circulating until pill has surfaced. M-I L.L.C. 721 W. 1 st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 IFE , .I I Interval Summary, Cont. Forest Oil Corporation Redoubt Shoal Unit #2 9,000 to 14104' md · ROP, GPM · Estimated ROP for this interval is 50 to 150 fi/hr. - 8 112" Hole J,,qN 2., 4 2001 Alaska Oil & Gas Cons. Commission AnChorage · 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 controled with moderate additions of Safecarb and/or Liquid Casing. 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 2- 4 ppb Ventrol 40 lto the mud system depending on the severity of the problem. · For severe coal sloughing, a concentrated pill consisting of 15 - 20 ppb Ventro1401 may be spotted across the coal bed prior to POH 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 al~er 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 nmning 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 POH to run casing. 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 nmning speed for this interval in Virtural Hydraulics. · The IFE Mud Engineer will communicate daily with the In Office IFE Coordinator. · VOLUME USAGE · Estimated fluid volume required for this interval is 830 barrels not including 1400 barrels from Well RU #1. M-I/;.£.c. 721 W. I st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 IFE Interval Summary RECE IVE Anch0ra.qe Forest Oil Corporation Redoubt Shoal Unit #2 Mixing Procedure Place 20 bbls oil mud in slugging pit. Add blend of lost circulation material. Spot across theft zone. iii~i":i'?:¢;:!'p"i~Sd:~iSt..:..;.;'.'::. .i :'7'::'.::i;.Oil',.'MUd'.:i' ' Vedtro140'i. Spot Ventrol pill across suspected coal bed ;!;:~;¢.:~;;.':~;:i.:.i..'i.i.;::..,;..:'.:i'.::. "..-,.. '".'.~i::.;.~!!,ii::.'"'.ii'; "..../:.' ' "'... :'"' ' PPB 20 bbls 15 - 20 ppb prior to pulling out of hole for trip. Mixing Procedure · Place 35 bbls oil mud in slugging pit. Add 15 - 20 ppb'Ventrol 401. Spot across theft zone and apply squeeze pressure not greater than annular pressure loss. M-I £.£.c. 721 W. 1 st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 IFE Interval Summary, Cont. Forest Oil Corporation Redoubt Shoal Unit #2 14,104 to 15,593' md - 6 314" Hole · ROP, GPM · Estimated ROP for this interval is 20 fi/hr. · Estimated flowrate for this interval is 250 GPM. · Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. · Lost Circulation · Seepage losses may be controled with moderate additions of Safecarb and/or Liquid Casing. Severe lost circulation should bc handled with LCM pills such as the one listed for this interval · Coal Beds · Sloughing/nmning coal should be treated by adding 2 -4 ppb Ventrol 401 to the mud system depending on the severity of the problem. · For severe coal sloughing, a concentrated pill consisting of 15 - 20 ppb Ventrol 401 may be spotted across the coal bed prior to POH 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 pc- 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 bc conditioned prior to POH to run casing. Moderate or reduce yield point and progressive gel strengths with additions of base oil in order to reduce surge pressure while rmming casing. NOTE: See recommended liner running speed for this interval in Virtural Hydraulics/ · VOLUME USAGE · Estimated fluid volume required for this interval is 660 barrels of new volume. RECEIVED JAN 2 4 ZOO1 Alaska Oil & Gas Cons. Commission M-I L.L.C. 721 W. 1 st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 · Fax: (907) 279-6729 REDOUBT UNIT #2 PRESSURE INFORMATION The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the Redoubt Unit gl. 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 gl(as per 407 Comp Report, 10/15/68) EMW -8.27 ppg Gradient = 0.430 psi/ft Redoubt Bay Unit gl, 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 Calculating 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 gl well. 1) ASP = ((FG x .052) - 0.10) x D where: 2) ASP= 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 0.1'0 = gas gradient in psi/ft. D = true vertical Depth of casing seat in ft RKB OR FPP-( 1/3 x 0.10 x D) - (2/3 x .45 x D) RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 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 Surface Casing (13 3/8") ASP OR = ((FG x .052)- 0.10) x D = ((12.5 x .052)- 0.10) x 7525' = 4139 psi ASP = (7525' x .45) - ( 1/3 x .10 x 7525') - (2/3 x .45 x 7525) = 878 psi Drilling below Intermediate Casing (9 5/8") ASP OR = ((FG x .052)-0.10) x D = ((10.5 x .052)- 0.10) x 11591' = 5170 psi ASP = (11591' x .45) - (1/3 x .10 x 11591') - (2/3 x .45 x 11591') = 1352 psi Drilling below Drilling Liner (7-5/8") ASP OR = ((FG x .052)- 0.10) x D = ((10.5 x .052)- 0.10) x 12776' = 5698 psi ASP = (12776' x .45) - (1/3 x .10 x 12776') - (2/3 x .45 x 12776') = 1491 psi RECEIVED JI~N ~ ~ 2.001 Alaska Oil & Gas Cons. Commission Anchorage REDOUBT UNIT #2 CEMENTING PROGRAM RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Operator Name: Forest Oil Corp Well Name: Redoubt Unit #2 ~{ Job Description: Redoubt #2 Surface Date: January 8, 2001 Proposal No: 179651397C JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing Size/Weight: Pump Via Total Mix Water Required Pre-flush Water Density Lead Slurry Lead Slurry Density Yield Tail Slurry Tail Slurry Density Yield Displacement Drilling Mud Density Stage No: 1 Float 2,906 ft 3,200 ft 18.5 in 13 3/8in, 68 I bs/ft Ddll Pipe 0 30,393 gals 3,120 ft 0 bbls 8.4 ppg 595 sacks 12.5 ppg 2.10 cf/sack 825 sacks 15.8 ppg 1.16 cf/sack 462 bbls 9.0 ppg RECEIVED JAN 2 4 2001 Alaska Oil & Gas Cons. Commission Anchorage Report Printed on: January 8, 2001 2:53 PM Page 1 Gr4109 Operator Name: Forest Oil Corp Well Name: Redoubt Unit #2 i'" Job Description: Redoubt #2 Surface Date: January 8, 2001 Proposal No: 179651397C JOB AT A GLANCE (Continued) Stage No: 2 Pre-flush Water Density Lead Slurry 2nd Stage Lead Density Yield Tail Slurry 2nd Stage Tail Density Yield Displacement Drilling Mud Density 2,000 ft 40 bbls 8.4 ppg 1,413 sacks 12.5 ppg 2.10 cf/sack 461 sacks 15.8 ppg 1.16 cf/sack 462 bbls 9.0 ppg RECEIVED JAN 2 4 ZOO! Alaska Oil & Gas Cons. Commission Anchorage Gr4109 Page 2 Operator Name: Forest Oil Corp Well Name: Redoubt Unit #2 ~' Job Description: Redoubt #2 Surface Date: January 8, 2001 Proposal No: 179651397C VVELL DATA ANNULAR GEOMETRY r . ANNULAR I.D, · .(in) 34.000 CASING 18.500 HOLE MEASURED .:. I TRUE VERTICAL 200 I 200 3,200 I 2,906 SUSPENDED PIPES I::: . .DIAMETER lin) O,o,: ~i I I.D. 13.375I 12.415 I ,(msm):1 '~ MEASURED: ' I,:: TRUE:VERTICAL I68 I 3,200 I 2,906 STAGE: 2 Stage Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 2,000 ft 9.00 ppg Water Based 80 ° F 75° F VOLUME CALCULATIONS 80 ft x 1.0278 cf/It 1,620 fl x 0.8910 cf/it 300 ft x 0.8910 cf/it with 0 % excess = with 100 % excess = with 100 % excess = TOTAL SLURRY VOLUME = 82.2 cf 2886.8 cf 534.6 cf 3503.6 cf 625 bbls STAG E: 1 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. VOLUME CALCULATIONS 700 ft x 0.8910 cf/it 500 ft x 0.8910 cf/ft 80 ft x 0.8315 cf/it with 100 % excess = with 100 % excess = with 0 % excess = TOTAL SLURRY VOLUME = .-- 3,120 ft 9.00 ppg Water Based 93 o F 85 o F RECEIVED JA~ ~ 4 2001 Alaska 0il & Gas Cons, Commission Anchorage 1248.9 cf 891.0 cf 66.5 cf (inside pipe) 2206.4 cf 393 bbls Gr4115 Report PriMed on: Janua~ 8, 2001 2:54 PM Page 3 Operator Name: Forest Oil Corp Well Name: Redoubt Unit #2 i' Job Description: Redoubt #2 Surface Date: January 8, 2001 Proposal No: 179651397C FLUID SPECIFICATIONS STAGE NO.: 1 Pre-flush VOLUME VOLUME FLUID CU-FT FACTOR Lead Slurry 1249 I 2.1 Tail Slurry 958 I 1.16 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) 0.0 bbls Water @ 8.4 ppg AMOUNT AND TYPE OF CEMENT = 595 sacks Class G Cement + 0.5% bwoc Calcium Chloride + 0.4% bwoc CD-32 + 1 gals/100 sack FP-6L + 2% bwoc Sodium Metasilicate + 106% Fresh Water = 825 sacks Class G Cement + 1.5% bwoc Calcium Chloride + 0.3% bwoc CD-32 + 1 gals/100 sack FP-6L + 44.1% Fresh Water 462.0 bbls Drilling Mud @ 9 ppg SLURRY SLURRY NO. 1 NO. 2 12.50 15.80 2.10 1.16 11.95 4.97 11.96 4.98 RECEIVED 4 2001 Alaska Oil & Gas Cons. Commission Anchorage Gr4129 Page 4 Operator Name: Forest Oil Corp Well Name: Redoubt Unit #2 i Job Description: Redoubt #2 Surface Date: January 8, 2001 Proposal No: 179651397C FLUID SPECIFICATIONS (Continued) STAGE NO.: 2 Pre-flush VOLUME VOLUME FLUID CU-FT FACTOR Lead Slurry 2~9 I 2.1 Tail Slum/ 535 I 1.16 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) 40.0 bbls Water @ 8.4 ppg AMOUNT AND TYPE OF CEMENT = 1413 sacks Class G Cement + 0.5% bwoc Calcium Chloride + 0.4% bwoc CD-32 + 1 gals/100 sack FP-6L + 2% bwoc Sodium Metasilicate + 106% Fresh Water = 461 sacks Class G Cement + 1.5% bwoc Calcium Chloride + 0.3% bwoc CD-32 + 1 gals/100 sack FP-6L + 44.1% Fresh Water 462.0 bbls Drilling Mud @ 9 ppg SLURRY SLURRY NO. 1 NO. 2 12.50 15.80 2.10 1.16 11.95 4.97 11.96 4.98 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Gr4129 RepoA Prin~ed on: January 8. 2001 2:54 PM Page 5 Operator Name: Well Name: Job Description: Date: Forest Oil Corp Redoubt Unit #2 Redoubt #2 Intermediate January 8, 2001 Proposal No: 179651397C JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing Size/Weight: Pump Via Total Mix Water Required Pre-flush Water + 1% MCS-AG Density Lead Slurry Inter. Lead Density Yield Tail Slurry Int. Tail Density Yield Displacement Drilling Mud Density Casing 7,525 ff 9,000 ff 12.25 in 9 5/8in, 47 Ibs/ft 9 5/8" O.D. (8.681" .I.D) 47 # 3,343 gals 28 bbls 8.4 ppg 195 sacks 12.5 ppg 2.09 cf/sack 206 sacks 15.8 ppg 1.15 cf/sack 653 bbls 9.3 ppg RECEIVED JAN B 2.001 Alaska Oil & Gas Cons. Commissiorl Anchorage Gr4109 Report Printed on: Janua~ 8, 2001 2:54 PM Page 8 Operator Name: Forest Oil Corp ii, Well Name: Redoubt Unit #2 Job Description: Redoubt #2 Intermediate Date: January 8, 2001 Proposal No: 179651397C WELL DATA ANNULAR GEOMETRY ' "' ANNULARI.D~' · · . .'(in):' . · I: "' "M~SURED:": .' !:'" ·TRUEVERTICAL 12.415 CASING I 3,200 I 2,906 12.250 HOLE I 9,000 I 7,525 SUSPENDED PIPES I. : .'DIAMETER, : (in): :: ' IWEI'(S'HT'I::: :i:::~:' ':::':":;:':,: :.::: :::::::::::::::::::::::::::: '1 o,D;' I , I,D, : ': I':(~bS/ffi' I. ':.', ::M~SUR:ED' ,,:: :I::,TR:UE::,VERTICAL,,':I 9.625 I 0.68a I47 I 9,000 I 7,525 I Float Collar set @ 8,920 ft Mud Density 9.50 ppg Mud Type Water Based Est. Static Temp. 125 ° F Est. Circ. Temp. 119 ° F VOLUME CALCULATIONS 1,000 ft x 0.3132 cf/ft 500 ft x 0.3132 cf/ft 80 ft x 0.4110 cf/ft with 30 % excess = with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 408.3 cf 204.1 cf 32.9 cf (inside pipe) 645.3 cf 115 bbls RECEIVED Alaska 0il & Gas Cons. Commission Anchorage Gr4115 Report PHnted on: Januanj 8, :2001:2:54 PM Page 9 Operator Name: Well Name: Job Description: Date: Forest Oil Corp Redoubt Unit #2 Redoubt #2 Intermediate January 8, 2001 Proposal No: 179651397C FLUID SPECIFICATIONS Pre-flush VOLUME FLUID CU-FT VOLUME FACTOR Lead Slurry 408 I 2.09 Tail Slurry 237 I 1.15 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) AMOUNT AND TYPE OF CEMENT -- 195 sacks Class G Cement + 0.4% bwoc CD-32 + 1 gals/100 sack FP-6L + 2% bwoc Sodium Metasilicate + 105.8% Fresh Water = 206 sacks Class G Cement + 0.3% bwoc CD-32 + 0.4% bwoc FL-33 + 1 gals/100 sack FP-6L + 43.9% Fresh Water '653.0 bbls Drilling Mud @ 9.3 ppg SLURRY SLURRY NO, 1 NO. 2 12.50 15.80 2.09 1.15 11.92 4.94 11.93 4.95 RECEIVED JAN g 4 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Gr4129 Rel:.:)rt P.n~ed on: January 8, 2001 2:54 PM Page 10 Operator Name: Forest Oil Corp .( Well Name: Redoubt Unit #2 Job Description: Redoubt #2 Drilling Liner Date: January 8, 2001 Proposal No: 179651397C JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Liner Size/Weight: Pump Via Total Mix Water Required Pre-flush Water + 1 gpb MCS-AG Weighted Spacer MCS-4D Density Cement Slurry Drilling Liner Density Yield Displacement Drilling Mud Density 11,591 ft 14,104 ft 8.5 in 7 5/8in, 29.7 Ibs/ff Drill Pipe 4 1/2" O.D. (3.500" .I.D) 21.36 # 735 gals 20 bbls 30 bbls 10.5 ppg 149 sacks 15.8 ppg 1.15 cf/sack 345 bbls 9.6 ppg RECE,'VE:D - Alaska 0il & Gas Cons. Commission Anchorage Gr410g Repolt Prir~ed on: January 8, 2001 2:54 PM Page 12 Operator Name: Forest Oil Corp Well Name: Redoubt Unit ,~2 Job Description: Redoubt #2 Ddlling Liner Date: January 8, 2001 Proposal No: 179651397C WELL DATA ANNULAR GEOMETRY ANNULAR LD, '- · (in):., 8.681 CASING 8.500 HOLE MEASURED · I' TRUE VERTICAL I 9,ooo I 7,525 I 14,104 I 11,591 SUSPENDED PIPES : DiAMETER./(in): O'.D:: I'' 'I,D, I: (Ibs/ff)::.:l ':M~SURED I :TRUE VERTICAL . 7.625 I 6.875 I 29.7 I 14,104 I 11,591 Drill Pipe 4.5 (in) OD, 3.5 (in) ID, 21.36 (lbs/fi) set @ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 8,800 ft 8,800 ft 14,024 ft 9.60 ppg Oil Based 173 ° F 139 ° F VOLUME CALCULATIONS 1,500 ft x 0.0770 cf/ft 80 ft x 0.2578 cf/ft with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 150 cf 21 cf (inside pipe) 171 cf 30 bbls RECEIVED JAN 2, 4 2001 Alaska Oil & Gas Cons. Commission Anchorage Gr4117 Page 13 Operator Name: Forest Oil Corp Well Name: Redoubt Unit #2 t. Job Description: Redoubt #2 Drilling Liner Date: January 8, 2001 Proposal No: 179651397C FLUID SPECIFICATIONS Pre-flush Weighted Spacer VOLUME VOLUME FLUID CU-FT FACTOR Cement Slurry 171 I 1.15 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) 30.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 119 Ibs/bbl Badte, Bulk @ 10.5 ppg AMOUNT AND TypE OF CEMENT = 149 sacks Class G Cement + 0.3% bwoc CD-32 + 0.6% bwoc FL-33 + I gals/100 sack FP-6L + 0.05% bwoc Sodium Metasilicate + 43.8% Fresh Water 344.6 bbls Drilling Mud @ 9.6 ppg SLURRY NO. i 15.80 1.15 4.93 4.94 RECEIVED JAN 2 ,~ ZOOl Alaska Oil & Gas Cons. Commission Anchorage Gr412~ Page 14 Operator Name: Forest Oil Corp Well Name: Redoubt Unit #2 Job Description: Redoubt #2 Production Liner Date: January 8, 2001 Proposal No: 179651397C JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Liner Size/Weight: Pump Via Total Mix Water Required Pm-flush Water + MCS AG Density Weighted Spacer MCS-4D Density Cement Slurry Liner Slurry Density Yield Displacement Drilling Mud Density 12,776 ft 15,593 ft 6.75 in 5 1/2in, 17 Ibs/ft Drill Pipe 4 112" O.D. (3.400" .I.D) 24.66 # 807 gals 20 bbls 8.4 ppg 30 bbls 10.5 ppg 165 sacks 15.8 ppg 1.16 cf/sack 194 bbls 9.8 ppg CE VED JI~N 2, z~ ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Gr4109 Operator Name: Forest Oil Corp Well Name: Redoubt Unit #2 '~' Job Description: Redoubt #2 Production Liner Date: January 8, 2001 Proposal No: 179651397C WELL DATA ANNULAR GEOMETRY 6.875 CASING I 4, o4 I 11,591 6.750 HOLE I 15,593 I 12,776 SUSPENDED PIPES : ':O:i'D:"':::. :'::':,!, '1::'i::":':':': ::(l'bS/ft):1'::: ::.MEASURED.: :1 TRUE'VERTICAL 5.500 I 4.892 I I 15,503 I 12,776 Drill Pipe 4.5 (in) OD, 3.4 (in) ID, 24.66 (lbs/fi) set (~ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 13,904 ft 13,904 ft 15,513 ft 9.80 ppg Oil Based 195 o F 154°F VOLUME CALCULATIONS 200 ft x 0.0928 cf/ft 1,489 fi x 0.0835 cf/ff 80 fi x 0.1305 cf/fi with 0 % excess = with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 19cf 162 cf 10 cf (inside pipe) 191 cf 34 bbls RECEIVED JAN B 4. 2001 Alaska Oil & Gas Cons. Commission Anchorage Gr4117 Repolt Printed on: January 8, 2001 2:55 PM Page 17 Operator Name: Forest Oil Coq3 .. Well Name: Redoubt Unit #2 ~[ Job Description: Redoubt #2 Production Liner Date: January 8, 2001 Proposal No: 179651397C FLUID SPECIFICATIONS Pre-flush Weighted Spacer VOLUME VOLUME FLUID CU-FT FACTOR Cement Slurry 191 I 1.16 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) 30.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 119 Ibs/bbl Badte, Bulk @ 10.5 ppg AMOUNT AND TYPE OF CEMENT = 165 sacks Class G Cement + 0.35% bwoc R-3 + 0.6% bwoc CD-32 + 1 gals/100 sack FP-6L + 0.15% bwoc Sodium Metasilicate + 0.8% bwoc BA-10A + 43.4% Fresh Water 193.5 bbls Ddlling Mud @ 9.8 ppg SLURRY NO. 1 15.80 1.16 4.89 4.90 RECEIVED JAN 2, ,~ 2001 Alaska Oil & Gas Cons. Commission Anchorage Gr4129 Report PHn~ed on: January 8, 2001 2:55 PM Page t 8 D~t~c~O~ ~o6~ RECEIVED JAN 8 ,~ 2001 Alaska Oil & Gas Cons. Commission Anchorage 2~0626.00 60'41'43.75ZN lSt*40'14535W 1250- 2500- 3750- 5000- 6250- 7500- 8750- 10000- 11250- 12500- 13750- 1000 2000 3000 4000 5000 6000 8000 9000 I0000 11000 12000 COMPA~]Y D~TAIL~ Cook fmi, n I.Yror Sy~=m: I~CWSA ~ ~ S~+ ~ SURVEY PROC] RAM .[X'p~t.Fm ~ To $~/Plm Tool 90.0015593.15 Plm2:~h R~loubt U~..~ Wp2 V MWD WELLPA'I'H DETAILS Redoubt 82 12~.05~ West(-)/East(+) [2000fi/in] 3000 4000 5000 6000 -1000 0 1000 2000 7000 8000 9000 10000 I .... I,, ,,I,,,,I ,,,, t,,,, I,,, ,{ .... I,,,,I,,,,I .... I,,,, 1000 e~1000 o00 ' %oo = L{J c:~ g ' Redoubt ~I~it #2 Wp2 13000 14000 RedoubtHemlockTarget 15000 .Redoubtlghk#2 0 1250 2500 3750 5000 6250 7500 8750 10000 Vertical Section at 125.05° [2500fl./in] DRAF T M000,..., --2000.~. --3000~,,~ --4000 --5000 .-6000 SE~I'ION I)F.I'AtI,S gcc ~ Inc /L~ TVD ~ 'I~W'~ TF~e VScc ~.~ 0.~ 0.~ ~.~ 0.~ 0,~ 0.~ 0.~ ~.~ 3.~125.~~.~ 4.51 ~ I.~1~.05 7.g5 ll~.~ 7.~1~ 1~.~ -~ ~.~ 1,50 0.~ 1~.~ 13.~!~.~ 13~.3~-51.~ ~.63 Z~ 0.~ ~.~ 21~.48 37.21 125.05 21~ -2~.7l~.78 3,~ 0.~ 4~.~ 141~ 37.21 I~.~ 1 I~1.~ ~383.~6247~ 0,~ 0.~ 7~1.92 R~t H~ek T~ 1~3.15 37.21 I~.~ 123~ 4~.71 6736.~ff~ 0.~ ~.~ . perry-Sun Drilling Alasl Planning Report - Geographic Company: Ccx~ Inlet D~te: lil2712000 Time: 14:25:58 Page: · I ii lqe. ld: COOK INLET Co~," rdlaate~,E) Reference: Well: Plan: Redoubt Unit ~2, Grid No'th ~te: Redoubt Ve~tle~ (TVD) Ref'em~ce:' Pla1:RedoubtUnit~2 90.0 Well: Plan:Redoubt Unit ~2 settee (VS) Reference: Well (0.00E,O.00N,~25.05Azi) WeBpath: Redoubt #2 Pi~a: Redoubt Unit #2 Wp2 --.....: . · ............... .-...'. -. .... · ........... _ ..:-.-_.. .. ................................... -,--.--:,,- .- ....... . -' - . ............. 2' .... Field: COOK INLET Alaska USA Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Oeo Datum: NAD27 (Clarke 1866) Coordinate STstem: Well Centre .bN's Datum: Mean Sea Level Ceomagnetic Model: BGGM2000 Site: Redoubt Site Position: Northing: 2451611.00 ft Latitude: 60 16 20.184 N From: Map Lasting: 2451611.00 ff Lonsimde: 139 13 4.141 W Position Uncertainty.: 0.00 ft North Reference: Grid Ground Level: 0.00 ft Grid Convergence: 9.13 deg Well: Plan: Redoubt Unit Surfaee Position: +N/-S -1661.96 ft Northing: 2449942.00 ft +E/-]~!~41490.54 ft Easting: 200626.00 ft Position Uncertatn~T: 0.00 ft Reference Point: +N/-$ -1661.96 ft Northing: 2449942.00 ft +E/-I~41490.54 ft Lasting: 200626.00 ft Measured Depth: 90.00 ff Vertical Depth: 90.00 ff Slot Name: Latitude: Longitude: Latitude: Longitude: Inclination: Azimuth: 60 41 43.752 N 151 40 14.535W 60 41 43.752 N 151 40 14.535W 0.00 deg 0.00 deg Wellpath: Redoubt//2 Drilled From: Well Ref. Point Tie-on Depth: -70.00 ft Current Datum: Plan: RedoubtUnitfY2 Height 90.00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/26/2004 Declination: 23.97 dog Field Strength: 56781 nT Mag Dip Angle: 75.28 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ff deg 0.00 0.00 0.00 125.05 Plan: Redoubt Unit #2 Wp2 Date Composed: 10/10/2000 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information ' . '.'~)..'../.". :..".l,:g....: i..":"'"'. ~"......:.:::.." '...' '~."..'. :.'.':.'. ::'~N,/,s '.:.'.' i..'. :.+~W:....'"":': ::' "..oLs.".:'..'. B.ila':'.;~:.'.: :..'T~r-:..:...'...i:: T~iO "".'..'..'~t ..:./. '....... '.. ':"d~.....:.. ':.": :..:. '-::. '.d~:' .' ,: ".: .:: i' ': ." '"" .: :" ft'.."":.... '.. '..' ': ...'.: ': ft.:..;.....'.. ~'..' '".i: .:' ':. '..ltl::;'."': :.....":..:...:..~t 'o~::.. ~! 0.0ft' ~eg/!o~"... '": ..: deg. 90.00 0,00 0.00 90.00 0.00 0.00 0.00 0.00 0.00 0.00 500,00 0.00 0.00 500,00 0.00 0.00 0,00 0.00 0.00 0.00 800.00 3.00 125.05 799.86 -4.51 6.43 1.00 1.00 0.00 125.05 1100.00 7.50 125.05 1098.53 -20.27 28.89 1.50 1.50 0.00 0.00 1400.00 t3.50 t25.05 1393.37 -51.65 73.63 2.00 ZOO 0:00 0.00 2190.48 37.21 125.05 2102.60 -244.71 348.78 3.00 3.00 0.00 0.00 14104.93 37.21 125.05 11591.00 -4383.43 6247.54 0.00 0.00 0.00 0.00 Redoubt Hemlock Targa 15093.15 37.21 125.05 12378.00 -4726.71 6736.80 0.00 0.00 0.00 0.00 15593.15 37.21 125.05 12776.19 -4900.40 6984.35 0.00 0.00 0.00 0.00 Section 1: Start Hold 90.~ 0.~ 0.~ 90.~ 0.00 0.~ 0.~ 0.~ 0.~ 0.~ 0.00 100.00 0.~ 0.~ 100,~ 0.00 0.00 0.~ 0.~ 0.~ 0.~ 0.00 200.~ 0.00 0.~ 200.~ 0.00 0.00 0,~ 0.~ 0.~ 0.00 0.00 300.~ 0.00 0,~ 300,~ 0,00 0.~ 0,~ 0,~ 0,~ 0,~ 0,00 400.00 0.00 0.~ 400.~ 0.00 0.~ 0,~ 0.00 0.~ 0.~ 0.00 ~0.~ 0.00 0.~ 500.00 0.00 0.~ 0.~ 0.00 0.~ 0.~ 0.00 RECEIVED JAN 2 4 2001 Alaska Oil & Gas Cons. Commission Anchorage ,perry-Sun Drilling Alas Planning Report- Geographic Flekl: COOK INLET' Co-erdinare(NE) !~, ferenee: Well: Plan: Redoubt Unit #2, Grid North Site: Redoubt Vertical (TVD) ~.~'~rence: Plall: R~lbubtI. Jn'~2 90.0 ' ' Well: Plan: Redoubt Unit #2 Section (VS) Refei, enee: Well (0.00E,O.00N,125:05Azi) Wellpath: Redoubt ~Y2 Plan: Redoubt Unit ~2 Wp2 ............................................................................. Se~_~ion 2: Start Build 1.00 600.00 1.00 125.05 599.99 -0.50 0.71 0.87 1.00 1.00 0.00 0.00 ~ 700.00 2.00 125.05 699.96 -2.OO 2.86 3.49 1.00 1.OO 0.OO 0.00 ~ 800.00 3.00 125.05 799.86 -4.51 6.43 7.85 1 .OO 1.OO 0.00 0.OO / Section 3: Start Build 1.50 I ~o.~ 4.~ 125.~ 809.05 -8.27 11.78 14.~ 1.~ 1.~ 0.~ 0.00 I 1000.~ 6.~ 125.~ 999.22 -13.52 19.27 23.~ 1.50 1.~ o.oo 0.00 I 1100.~ 7.~ 125.05 1098.53 -20.27 28.89 35.30 1.50 1.~ 0.~ 0.00 Section 4: Start Build 2.00 deg ff ff ff ft deg/100fl deg/looff, deg/100ft deg 1200.00 9.50 125.05 1197.42 -28.76 40.99 50.08 2.00 2.00 0.00 0.00 1300.00 11.50 125.05 1295.74 -39.22 55.91 68.30 2.00 2.00 0.00 0.00 1400.00 13.50 125.05 1393.37 -51.65 73.63 89.94 2.00 2.00 0.00 0.00 Section 5: Start Build 3.00 1500.OO 16.50 1600.00 19.50 1700.00 22.50 1800.00 25.50 1900.00 28.50 2000.00 31.50 2100.O0 34.5O 2183.73 37.01 2t 90.48 37.21 125.05 1489.95 125.05 1585.05 125.05 1678.39 125.05 1769.74 125.05 t858.83 125.05 1945.42 125.05 2029.28 125.05 2097.22 t25.05 2102.60 -66.51 94.82 115.82 3.00 3.OO 0.00 0.00 -84.26 120.11 146.72 3.00 3.00 0.OO 0.00 -104.84 149.45 182.55 3.00 3.00 0.00 0.00 -128.19 182.74 223.22 3.00 3.00 0.00 0.00 -154.26 219.90 268.6t 3.00 3.00 0.OO 0.OO -182.97 260.83 318.61 3.00 3.00 0.00 0.00 -214.25 305.41 373.07 3.00 3.00 0.00 0.00 -242.35 345.46 421.99 3.00 3.00 0.01 0.06 -244.71 348.78 426.06 3.00 3.00 0.00 0.05 Section 6: Start Hold 2200.00 37.21 2300.00 37.21 2400.00 37.21 2500.OO 37.21 2600.00 37.2t 27O0.00 37.21 2800.00 37.21 2900.00 37.21 3O00.00 '37.21 3t00.00 37.21 32OO.00 37.21 3300.00 37.21 3400.OO 37.21 3500.00 37.21 3600.00 37.21 3700,00 37.21 3800.00 37.21 3900.00 37.21 4000.00 37.21 4100.00 37.21 4200.00 37.21 4300.00 37.21 4400.00 37.21 4500.00 37.21 4600.00 37.21 4700.00 37.21 125.05 2110.18 125.05 2189.82 125.05 2269.46 125.05 2349.10 t25.05 2428.74 125.05 2508.37 125.05 2588.01 125.05 2667.65 125.05 2747.29 t25.05 2826.92 125.05 2906.56 125.05 2986.20 125.05 3065.84 125.05 3145.48 125.05 3225.11 125.05 3304.75 125.05 3384.39 125.05 3464.03 125.05 3543.66 125.05 3623.3O 125.05 3702.94 125.05 3782.58 125.05 3862.21 125.05 3941.85 125.05 4021.49 125.05 4101.13 -248.01 353.49 431.82 0.00 O.OO 0.00 0.00 -282.75 403.00 492.30 0.00 0.00 0.00 0.00 -317.49 452.51 552.78 0.00 O.OO 0.00 0.00 -352.22 502.02 613.26 O.OO 0.00 0.00 0.00 -386.96 551.53 673.74 O.OO 0.00 0.00 0.00 -421.70 601.94 734.22 0.OO 0.00 0.00 0.00 -456.43 650.55 794.70 0.OO 0.00 0.00 0.00 -491.17 700.06 855.18 0.OO 0.00 0.00 0.OO -525.91 749.57 915.66 0.00 0.OO 0.00 0.00 -560.65 799.08 976.14 0.OO 0.00 0.00 0.00 -595.38 848.59 1036.62 0.00 0.00 0.OO 0.00 -630.12 898.10 1097.10 0.00 0.00 0.00 0.00 -664.86 947.60 1157.58 0.OO 0.OO 0.00 0.00 -699.59 997.11 1218.06 0.00 0.00 0.OO 0.00 -734.33 1046.62 1278.54 0.00 0.00 0.00 0.00 -769.07 1096.13 1339.02 O.OO 0.00 0.00 0.00 -803.80 1145.64 1399.50 O.OO 0.00 0.00 0.00 -838.54 1195.15 1459.98 O.OO O.OO 0.00 0.00 -873.28 1244.66 1520.46 0.00 0.OO 0.00 0.00 -908.02 1294.17 1580.94 0.00 0.00 0.00 0.00 -942.75 1343.68 1641.42 0.OO 0.00 0.00 0.00 -977.49 1393.19 1701.90 0.00 0.00 0.00 0.00 -1012.23 1442.70 1762.38 0.00 0.00 0.OO 0.00 -1046.96 1492.21 1822.86 0.OO 0.00 0.00 0.00 -1081.70 1541.72 t883.34 0.00 0.OO 0.OO 0.00 -1116.44 1591.23 1943.82 0.00 0.00 0.00 0.00 perry-Sun Drilling AlaskL Planning Report- Geographic ~M: cOOK INLET Co-ordinate~N~-') Reference: Well: Plah: Redoqbt Unit.#2, Grid N' .o~.:. ...". ' Site: R~loubt Vertical (TVD) ReJ'erence: Plan: RedoubtUnrdt2 90.0 ., Well: Pian: RedcxJbt Unit ~ ~'flon (¥S) Reference: Well (0.0~E.,0.00N,.125.0~i): . ..'::' Wellpalh: Redoubt ~ Hun: Redoubt Unit #2 Wp2 . .. Section 6: Start Ho~d 4800.00 37.21 125.05 4180.77 -1151.18 1640.73 2004.30 4900.00 37.21 125.05 4260.40 -1185.91 1690.24 2064.78 5000.00 37.21 125.05 4340.04 -1220.65 1739.75 2125.26 5100.00 37.21 125.05 4419.68 -1255.39 1789.26 2185.74 5200.00 37.21 125.05 4499.32 -1290.12 1838.77 2246.22 5300.00 37.21 125.05 4578.95 -1324.86 1888.28 2306.70 5400.00 37.21 125.05 4658.59 -1359.60 1937.79 2367.18 5500.00 37.21 125.05 4738.23 -1394.33 1987.30 2427.68 5500.00 37.21 t25.05 4817.87 -t429.07 2036.81 2488.14 5700.00 37.21 125.05 4897.51 -1463.81 2086.32 2548.62 5800.00 37.21 125.05 4977.14 -1498.55 2135.83 2609.10 5900.00 37.21 125.05 5056.78 -1533.28 2185.34 2669.58 6000.00 37.21 125.05 5136.42 -1568.02 2234.85 2730.06 6100.00 37.21 125.05 5216.06 -1602.76 2284.36 2790.54 6200.00 37.21 125.05 5295.69 -1637.49 2333.86 2851.02 6300.00 37.21 125.05 5375.33 -1672.23 2383.37 2911.50 6400.00 37.21 125.05 5454.97 -1706.97 2432.88 2971.98 6500.00 37.21 125.05 5534.61 -1741.71 2482.39 3032.46 6600.00 37.21 125.05 5614.25 -1776.44 2531.90 3092.94 6700.00 37.21 t25.05 5693.88 -1811.18 2581.41 3153.42 6800.00 37.21 125.05 5773.52 -1845.92 2630.92 3213.90 6900,00 37.21 125.05 5853,16 -1880.65 2680.43 3274.38 7000.00 37.21 125.05 5932.80 -1915.39 2729.94 3334.86 7100.00 37.21 125.05 6012.43 -1950.13 2779.45 3395.34 7200.00 37.21 125.05 6092.07 -1984.86 2828.96 3455.82 7300.00 37.21 t25.05 6171.71 -2019.60 2878.47 3516.30 7400.00 37.21 125.05 6251.35 -2054.34 2927.98 3576.78 7500.00 37.21 125.05 6330.98 -2089.08 2977.48 3637.26 7600.00 37.21 125.05 6410.62 -2123.81 3026.99 3697.74 7700.00 37.21 125.05 6490.26 -2158.55 3076.50 3758.22 7800.00 37.21 125.05 6569.90 -2193.29 3126.01 3818.70 7900.00 37.21 125.05 6649,54 -2228.02 3175.52 3879.18 8000,00 37.21 t25.05 6729, t 7 -2262.76 3225.03 3939.66 8100.00 37.21 125.05 6808.81 -2297.50 3274.54 4000.14 8200,00 37.21 125,05 6888,45 -2332,23 3324,05 4060.62 8300.00 37.21 125.05 6968.09 -2366.97 3373.56 4121.10 8400.00 37.21 125.05 7047.72 -2401.71 3423.07 4181.58 8500.00 37.21 125.05 7127.36 -2436.45 3472.58 4242.06 8600.00 37.21 125.05 7207.00 -2471.18 3522.09 4302.54 8700.00 37.21 125.05 7286.64 -2505.92 3571.60 4363.02 8800.00 37.21 125.05 7366.28 -2540.66 3621.11 4423.50 8900.00 37.21 125.05 7445.91 -2575.39 3670.61 4483.98 9000.00 37.21 125.05 7525.55 -2610.13 3720.12 4544.46 9100.00 37.21 125.05 7605.19 -2644.87 3769.63 4604.94 9200.00 37.21 125.05 7684.83 -2679.61 3819.14 4665.42 9300.00 37.21 125.05 7764.46 -2714.34 3868.65 4725.90 9400.00 37.21 125.05 7844.10 -2749.08 3918.16 4786.38 9500.00 37.21 125.05 7923.74 -2783.82 3967.67 4846.86 9600.00 37.21 125.05 8003.38 -2818.55 4017.18 4907.34 9700.00 37.21 125.05 8083.01 -2853.29 4066.69 4967.82 9800.00 37.21 125.05 8162.65 -2888.03 4116.20 5028.30 9900.00 37.21 125.05 8242.29 -2922.76 4165.71 5088.78 10000.00 37.21 t25.05 8321.93 -2957.50 4215.22 5149.26 10100.00 37.21 125.05 8401.57 -2992.24 4264.73 5209.74 10200.00 37.21 125.05 8481.20 -3026.98 4314.24 5270.22 10300.00 37.21 125.05 8560.84 -3061.71 4363.74 5330.70 10400.00 37.21 125.05 8640.48 -3096.45 4413.25 5391.18 10500.00 37.21 125.05 8720.12 -3131.19 4462.76 5451.66 10600.00 37.21 125.05 8799.75 -3165.92 4512.27 5512.14 10700.00 37.21 125.05 8879.39 -3200.66 4561.78 5572.62 10800.00 37.21 125.05 8959.03 -3235.40 4611.29 5633.10 10900.00 37.21 125.05 9038.67 -3270.14 4660.80 5693.58 11000.00 37.21 125.05 9118.31 -3304.87 4710.31 5754.06 11100.00 37.21 125.05 9197.94 -3339.61 4759.82 5814.54 _,perry-Sun Drilling AlasE Planning Report - Geographic [.,?ompany: Cook InM l~te: 11/27/2000 Time: 14:25:58 P~ge: iqdd: ' COOK INLET , Ce-erdlaate~..'E) Referem:. e: Well: Plan: Redoubt Unit #2, Grid North Site I~edoubt ' Vedleal O'VD) Reference: 'Plan: RedoubtUniUf2 90.0 Well: Plan: Redoubt Unit ~2 St, etlon 0/S) Reference: Well (0.00E~0.00N;125.05Azi) Wdlpath: Redoubt ~.2' . ................. Plan: .. ....... Redou..~Un. it_~_._..W_p..2. ........ Section 6: Start Hold n deg deg ff n ft fl deg/100ft deg/100ft deg/1O0ft deg .......................................................... 11200.00 37.21 125.05 9277.58 -3374.35 4809.33 5875.02 0.00 0.00 0.00 0.00 11300.00 37.21 125.05 9357.22 -3409.08 4858.84 5935.50 0.00 0.00 0.00 0.00 11400.00 37.21 125.05 9436.86 -3443.82 4908.35 5995.98 0.00 0.00 0.00 0.00 11500.00 37.21 125.05 9516.49 -3478.56 4957.86 6056.46 0.00 0.00 0.00 0.00 11600.00 37.21 125.05 9596.13 -3513.29 5007.37 6116.94 0.00 0.00 0.00 0.00 11700.00 37.21 125.05 9675.77 -3548.03 5056.87 6177.42 0.00 0.00 0.00 0.00 11800.00 37.21 125.05 9755.41 -3582.77 5106.38 6237.90 0.00 0.00 0.00 0.00 11900.00 37.21 125.05 9835.05 -3617.51 5155.89 6298.38 0.00 0.00 0.00 0.00 12000.00 37.21 125.05 9914.68 -3652.24 5205.40 6358.86 0.00 0.00 0.00 0.00 12100.00 37.21 125.05 9994.32 -3686.98 5254.91 6419.34 0.00 0.00 0.00 0.00 12200.00 37.21 125.05 10073.96 -3721.72 5304.42 6479.82 0.00 0.00 0.00 0.00 12300.00 37.21 125.05 10153.60 -3756.45 5353.93 6540.30 0.00 0.00 0.00 0.00 12400.00 37.21 125.05 10233.23 -3791.19 5403.44 6600.78 0.00 0.00 0.00 0.00 12500.00 37.21 125.05 10312.87 -3825.93 5452.95 6661.26 0.00 0.00 0.00 0.00 12600.00 37.21 125.05 10392.51 -3860.67 5502.46 6721.74 0.00 0.00 0.00 0.00 12700.00 37.21 125.05 10472.15 -3895.40 5551.97 6782.22 0.00 0.00 0.00 0.00 12800.00 37.21 125.05 10551.78 -3930.14 5601.48 6842.70 0.00 0.00 0.00 0.00 12900.00 37.21 125.05 10631.42 -3964.88 5650.99 6903.18 0.00 0.00 0.00 0.00 13000.00 37.21 125.05 10711.06 -3999.61 5700.49 6963.66 0.00 0.00 0.00 0.00 13100.00 37.21 125.05 10790.70 -4034.35 5750.00 7024.14 0.00 0.00 0.00 0.00 13200.00 37.21 125.05 10870.34 -4069.09 5799.51 7084.62 0.00 0.00 0.00 0.00 13300.00 37.21 125.05 10949.97 -4103.82 5849.02 7145.10 0.00 0.00 0.00 0.00 13400.00 37.21 125.05 11029.61 -4138.56 5898.53 7205.58 0.00 0.00 0.00 0.00 13500.00 37.21 125.05 11109.25 -4173.30 5948.04 7266.06 0.00 0.00 0.00 0.00 13600.00 37.21 125.05 11188.89 -4208.04 5997.55 7326.54 0.00 0.00 0.00 0.00 13700.00 37.21 125.05 11268.52 -4242.77 6047.06 7387.02 0.00 0.00 0.00 0.00 13800.00 37.21 125.05 11348.16 -4277.51 6096.57 7447.50 0.00 0.00 0.00 0.00 13900.00 37.21 125.05 11427.80 -4312.25 6146.08 7507.98 0.00 0.00 0.00 0.00 14000.00 37.21 125.05 11507.44 -4346.98 6195.59 7568.46 0.00 0.00 0.00 0.00 14104.93 37.21 125.05 11591.00 -4383.43 6247.54 7631.92 0.00 0.00 0.00 0.00 Section 7: Start Hold .... Ml):.'.:'::'..'~i'::i.'i. ln~l..'..'::;/.!'.?:;.::~'.i.',i..:i?'.i." i~".":i:?''' .+N/-$".~::.',.,'~:'+glW""."i, 'V$ .~:.::ii..~..`:::~:..~)L$......~.~.;...!.~"~d?!.::::..:~.T~urn....:.....:.....!~..TF~ .':..:.~i...'!i....::/i.::,.....i....!'.!i::i.:i.:'::,.i:i: '.ft..' ..!:'::.'../i. deg: '.,...;:.:.,'.'...':.!'.:~leg:i,:':.":.?~.:' .:-'...., ff.....'....: ".'ft. :.'.." .:i-,',:'.. "ft .":..':":" .'. ft' .:'"'i:'?'..: ~.lOOff!(d~l.~.i'::deg/ioOfi;","'..:::..:.deg ( . .. :... ·: :...... · .. ,.,., ...': ,...-~ .....: ......:...:..... ...... . ,. ,.... . .........,: ...... ,,,.. ..... . ........ . ....... . ,. .. ..... 14200.00 37.21 125.05 11666.71 -4416.46 6294.61 7689.42 0.00 0.00 0.00 0.00 14300.00 37.21 125.05 11746.35 -4451.19 6344.12 7749.90 0.00 0.00 0.00 0.00 14400.00 37.21 125.05 11825.99 -4485.93 6393.62 7810.38 0.00 0.00 0.00 0.00 14500.00 37.21 125.05 11905.63 -4520.67 6443.13 7870.86 0.00 0.00 0.00 0.00 14600.00 37.21 125.05 11985.26 -4555.41 6492.64 7931.34 0.00 0.00 0.00 0.00 14700.00 37.21 125.05 12054.90 -4590.14 6542.15 7991.82 0.00 0.00 0.00 0.00 14800.00 37.21 125.05 12144.54 -4624.88 6591.66 8052.30 0.00 0.00 0.00 0.00 14900.00 37.21 125.05 12224.18 -4659.62 6641.17 81t2.78 0.00 0.00 0.00 0.00 15000.00 37.21 125.05 12303.82 -4694.35 6690.68 8173.26 0.00 0.00 0.08 0.00 15093.15 37.21 125.05 12378.00 -4726.71 6736.80 8229.60 0.00 0.00 0.08 0.00 Section 8: Start Hold 15100.00 37.21 125.05 12383.45 -4729.09 6740.19 8233.74 0.00 0.00 0.00 0.00 15200.00 37.21 125.05 12463.09 -4763.83 6789.70 8294.22 0.00 0.00 0.00 0.00 16300.00 37.21 125.05 12542.73 -4798.57 6839.21 8354.70 0.00 0.00 0.00 0.00 .LLJ 15400.00 37.21 125.05 12622.37 -4833.30 6888.72 8415.18 0.00 0.00 0.00 0.00 15500.00 37.21 125.05 12702.00 -4868.04 6938.23 8475.66 0.00 0.00 0.00 0.00 15558.67 37.21 125.05 12748.73 -4888.42 6967.27 8511.14 0.00 0.00 0.00 0.00 15593.15 37.21 125.05 12776.19 -4900.40 6984.35 8532.00 0.00 0.00 0.00 0.00 LJJ perry-Sun Drilling AlaskL Planning Report - Geographic I I~,M: COOK INLET .. . . Ce~grdinate(NE)'~eference: Well: plan: Redoubt Unit ~2, Grid North Site: Redoubt . , · ,,, Verttcal(3'VD) Re,~,erence: Plah: RedoubtUnit~2 90.0, i We#: Plan: Redoubt Unit #2 - .%Ftion 0/S) Reference: Well (0.00E,0.1)ON,125.05A~) i Wellpath: Redoubt #2 , Plan: Redoubt Unit #2 Wp2 .................... j Sn~ey '.'i'~C~ /".:. '*'."-'.: ~'~:~:.~:~:':.":' .: i~..' .~.!,'.;~'~.-~"::'.~:...i.':.' :4'' .';"~:~.~,~'~;"~::.' ..... :'" ' ....... '" ". ................................ ..... ~ :'.~".-:. '.'." .? ....... ....... ..... . ..... ? ........ !t. ................. , .,: 00.00 0.00 0.00 90.00 0.00 0.00 24400042.00 200526.00 O0 41 43.752 Iq 151 40 14.5~ W 100.00 0.1210 0.00 100.00 0.00 0.00 2440042.00 2001526.00 ~ 41 43.752 Iq 151 40 14.,535 W 200.00 0.1210 0.00 200.00 0.00 0.00 2440042.00 200~6.00 ~ 41 43.752 lq 151 40 14.5~ W 300.00 0.00 0.00 300.00 0.00 0.00 2440042.00 200~26.00 ~ 41 43.752 lq 151 40 14.535 W 400.00 0.00 0.00 400.00 0.00 0.00 2440042.00 200026.00 ~ 41 43.752 Iq 151 40 14.535 W ,500.00 0.00 0.00 500.00 0.03 0.00 2440042.00 200626.00 CoO 41 43.752 lq 151 40 14.,535 W 600.00 1.00 125.05 599.00 -0.50 0.71 2440041.50 200~.6.7t 60 41 43.747 lq 151 40 14.520 W 700.00 2.00 125.05 699.~ -2.00 2.86 2440040.00 200~28.86 60 41 43.733 lq 151 40 14.476 W 800.00 3.00 125.05 790.86 -4.51 0.43 2440937.49 200032.43 60 41 43.709 lq 151 40 14.403 W 900.00 4.50 125.05 899.65 -8.27 11.78 2449933.73 200637.78 60 41 43.673 N 151 40 14.294 W t000.00 6.00 125.05 999.22 -13.52 19.27 2449928.48 200645.27 60 41 43.623 N 151 40 14.141 W 1100.00 7.50 125.05 1098.53 -20.27 28.89 2449921.73 200654.89 60 41 43.559 N 151 40 13.944 W 1200.00 9.50 125.05 1197,42 -28.76 40.99 2449913,24 200666.99 60 41 43,479 N 151 40 13,697 W 1300.00 11.50 125.05 1295.74 -39.22 55.91 2449902.78 200681.91 60 41 43.380 N 151 40 13.392 W 1400.00 13.50 125.05 1393.37 -51.65 73.63 2449890.35 200699.63 60 41 43.262 N 151 40 13.030 W 1500.00 16.50 125.05 1489.95 -66.51 94.82 2449875.49 200720.82 60 41 43.121 N 151 40 12.597 W 1600.00 19.50 125.05 1585.05 -84.26 120.11 2449857.74 200746.11 60 41 42.952 N 151 40 12.080 W 1700.00 22.50 125.05 1678.39 -104.84 149.45 2449837.16 200775.45 60 41 42.757 N 151 40 11.480 W 1800.00 25.50 125.05 1769.74 -128.19 182.74 2449813.81 200808.74 60 41 42.535 N 151 40 10.800 W 1900.00 28.50 125.05 1858.83 -154.26 219.90 2449787.74 200845.90 60 41 42.288 N 151 40 10.040 W 2000.00 31.50 125.05 1945.42 -182.97 260.83 2449759.03 200886.83 60 41 42.016 N 151 40 9,204 W 2100.00 34.50 125.05 2029.28 -214.25 305.41 2449727.75 200931.41 60 41 41.719 N 151 40 8.292 W 2183.73 37.01 125.05 2097.22 -242.35 345.46 2449699.65 200971.46 60 41 41.452 N 151 40 7.474 W 2190.48 37.21 125.05 2102.60 -244.71 348.78 2449697.29 200974.78 60 41 41.430 N 151 40 7.406 W 2200.00 37.21 125.05 2110.18 -248.01 353.49 2449693.99 200979.49 60 41 41.399 N 151 40 7.310 W 2300.00 37.21 125.05 2189.82 -282.75' 403.00 2449659.25 201029.00 60 41 41,069 N 151 40 6.298 W 2400.00 37.2t 125.05 2269.46 -317.49 452.51 2449624.51 201078.5t 60 41 40.739 N t51 40 5,286 W 2500,00 37.21 t25.05 2349.10 -352.22 502.02 2449589,78 201128.02 60 41 40.410 N 151 40 4.274 W 2600,00 37.21 125.05 2428.74 -386,96 551.53 2449555,94 201177.53 60 41 40,080 N 151 40 3,262 W 2700.00 37.21 125.05 2508.37 -421.70 601.04 2449520.30 201227.04 60 41 39.751 N 151 40 2.250 W 2800.00 37.21 125.05 2588.01 -456.43 650.55 2449485.56 201276.55 60 41 39.421 N 151 40 1.239 W 2900.00 37.21 125.05 2667.65 -491.17 700.06 2449450.83 201326.06 60 41 39.091 N 151 40 0.227 W 3000.00 37.21 125.05 2747.29 -525.91 749.57 2449416.09 201375.57 60 41 38,762 N 151 39 59,215 W 3100.00 37.21 125,05 2826.92 -560.65 799.08 2449381.35 201425.08 60 41 38.432 N 151 39 58.203 W 3200.00 37.21 125.05 2906.56 -595.38 848.59 2449346.62 201474.59 60 41 38,103 N 151 39 57.191 W 3300.00 37.21 125.05 2986.20 -630.12 898.10 2449311.88 201524.10 60 41 37.773 N 151 39 56,180 W 3400.00 37,21 125,05 3065.84 -664.86 947.60 2449277.14 201573.61 60 41 37,443 N 151 39 55,168 W 3500,00 37.21 125.05 3145.48 -699.59 997.11 2449242.41 201623.12 60 41 37.114 N 151 39 54.156 W 3600.00 37.21 125.05 3225.11 -734.33 1046.62 2449207.67 201672.63 60 41 36.784 N 151 39 53.144 W 3700.00 37.2t 125.05 3304.75 -769.07 1096.13 2449172.93 201722.13 60 4t 36.455 N t51 39 52.132 W 3800.00 37,21 125,05 3384.39 -803,80 1145.64 2449138,19 201771.64 60 41 36,125 N 151 39 51.121 W 3900.00 37.21 125.05 3464.03 -838.54 1195.15 2449103.46 201821.15 60 41 35.795 N 151 39 50.109 W 4000.00 37.21 125.05 3543.66 -873.28 1244.66 2449068.72 201870.66 60 41 35,466 N 151 39 49.097 W 4100.00 37.21 125.05 3623.30 -908.02 t294.17 2449033.98 201920.17 60 41 35.136 N 151 39 48.085 W 4200.00 37.21 125.05 3702.94 -942.75 1343.68 2448999.25 201969.68 60 41 34.807 N 151 39 47.074 W 4300.00 37.21 125.05 3782.58 -977.49 1393.19 2448964.51 202019.19 60 41 34.477 N 151 39 46,062 W 4400.00 37.21 125.O5 3862.21 -1012.23 1442.70 2448929.77 202068.70 60 41 34.147 N 151 39 45.050 W 4500.00 37.21 125.05 3941.85 -1046.96 1492.21 2448895.03 202118.21 60 41 33.818 N 151 39 44.038 W 4600.00 37.21 125.05 4021.49 :1081.70 1541.72 2448860.30 202167.72 60 41 33.488 N 151 39 43.027 W 4700,00 37.21 125,05 4101.13 -1116.44 1591.23 2448825.56 202217.23 60 41 33,158 N 151 39 42,015 W 4800.00 37.21 125.05 4180.77 -1151.18 1640.73 2448790.82 202266.74 60 41 32,829 N 151 39 41,003 W 4900,00 37.21 125.05 4260.40 -1185.91 1690.24 2448756.09 202316.25 60 41. 32.499 N 151 39 39,991 W 5000.00 37.21 125.05 4340.04 -1220.65 1739.75 2448721.35 202365.76 60 4~ ~1~ ]~,~1 ~3,~ 38.980 W ALaska Oil & Gas Cons. Commission Anchorage ,perry-Sun Drilling Alaskt. Planning Report- Geographic ~eld: COOK INLET Co-ordluate~E).Reference: Wetl: Plan: Redoubt Unit #21Gdd Norlh site: Redoubt .... , Ve~ai ('I'Ve) R~..~ke~ce: Pt~':,R~dOUb~J'~ 90.0 ' Welh Plan: Redoubt Unit 02 S~'tlen 0~'S) Refembce: W~..I (0.00~.. ',0.00N,125.05Azi) Wellpath: Redoubt#2' Plan.~ : '. Redoubt Unit #2 Wp2 ...................................................................................... Survey MD Incl Aaim TVD +NFS +F./-W ff deg deg ft fl ft 5100.00 37.21 125.05 -----" ' 44'~',~:~8 ..... ~)~5'~';~9 1789.26 5200.00 37.21 125.05 4499.32 -1290.12 1838.77 5300.00 37.21 125.05 4578.95 -1324.86 1888.28 5400.00 37.21 125.05 4658.59 -1359,60 1937.79 5500.00 37.21 125.05 4738.23 -1394.33 1987.30 5600,00 37.21 125.05 4817.87 -1429.07 2036.81 5700.00 37.21 t25.05 4897.51 -1463.81 2086.32 5800.00 37.21 125.05 4977.14 -1498.55 2135.83 5,900.00 37.21 125.05 5056.78 -1533.28 2185.34 6000.00 37.21 125.05 5136.42 -1568.02 2234.85 6100.00 37.21 125.05 5216.06 -1602.76 2284.36 6200.00 37.21 125.05 5295.69 -1637.49 2333.86 6300.00 37.21 125.05 5375.33 -1672.23 2383.37 6400.00 37.21 125.05 5454.97 -1706.97 2432.88 6500.00 37.2t 125.05 5534.61 -1741.71 2482.39 6600.00 37.21 125.05 5614.25 -1776.44 2531.90 6700.00 37.21 125.05 5693.88 -1811.18 2581.41 6800.00 37.21 125.05 5773.52 -1845.92 2630.92 6900.00 37.21 t25.05 5853.16 -1880.65 2680.43 7000.00 37.21 125.05 5932.80 -1915.39 2729.94 7100.00 37.21 125.05 6012.43 -1950.13 2779.45 7200.00 37.21 125.05 6092.07 -1984.86 2828.96 7300.00 37.21 125.05 6171.71 -2019.60 2878.47 7400.00 37.21 125.05 6251.35 -2054.34 2927.98 7500.00 37.21 125.05 6330.98 -2089.08 2977.48 7600.00 37.21 125.05 6410.62 -2123.81 3026.99 7700.00 37.21 125.05 6490.26 -2t58.55 3076.50 7800.00 37.21 125.05 6569.90 -2193.29 3126.01 7900.00 37.21 125.05 6649.54 -2228.02 3175.52 8000.00 37.21 125.05 6729.17 -2262.76 3225.03 8100.00 37.21 125.05 6808.81 -2297.50 3274.54 8200.00 37.21 125.05 6888.45 -2332.23 3324.05 8300.00 37.21 125.05 6968.09 -2366.97 3373.56 8400.00 37.21 125.05 7047.72 -2401.71 3423.07 8500.00 37.21 125.05 7127.36 -2436.45 3472.58 8600.00 37.21 t25.05 7207.00 -2471.18 3522.09 8700.00 37.21 125.05 7286.64 -2505.92 3571.60 8800.00 37.21 125.05 7366.28 -2540.66 3621.11 8900.00 37.21 125.05 7445.91 -2575.39 3670.61 9000.00 37.21 125.05 7525.55 -2610.13 3720.12 9100.00 37.21 125.05 7605.19 -2644.87 3769.63 9200.00 37.21 125.05 7684.83 -2679.61 3819.14 9300.00 37.21 t25.05 7764.46 -2714.34 3868.65 9400.00 37.21 125.05 7844.10 -2749.08 3918. t6 9500.00 37.21 125.05 7923.74 -2783.82 3967.67 9600.00 37.21 125.05 8003.38 -2818.55 4017.18 9700.00 37.21 125.05 8083.01 -2853.29 4066.69 9800.00 37.21 125.05 8162.65 -2888.03 4116.20 9900.00 37.21 125.05 8242.29 -2922.76 4165.71 10000.00 37.21 125.05 8321.93 -2957.50 4215.22 10100.00 37.21 125.05 8401.57 -2992.24 4264.73 10200.00 37.21 125.05 8481.20 -3026.98 4314.24 Map '...Map <---. Ladmde ~ '<-- Longitnde ~=~ · Northing EastinR Deg Min. Sec Deg Min See ft 2448686.61 202415.27 60 41 31.840 N 151 39 37.968 W 2448651.87 202464.78 60 41 31.510 N 151 39 36.956 W 2448617.14 202514.28 60 41 31.180 N 151 39 35.945 W 2448582.40 202563.79 60 41 30.851 N 151 39 34.933 W 2448547.66 202613.30 60 41 30.521 N 151 39 33.921 W 2448512.93 202662.81 60 41 30.192 N 151 39 32.910 W 2448478.19 202712.32 60 41 29.862 N 151 39 31.898 W 2448443.45 202761.83 60 41 29.532 N 151 39 30.886 W 2448408.71 202811.34 60 41 29.203 N 151 39 29.875 W 2448373.98 202860.85 60 41 28.873 N 151 39 28.863 W 2448339.24 202910.36 60 41 28.543 N 151 39 27.851 W 2448304.50 202959.87 60 41 28.214 N 151 39 26.840 W 2448269.77 203009.38 60 41 27.884 N 151 39 25.828 W 2448235.03 203058.89 60 41 27.554 N 151 39 24.816 W 2448200.29 203108.40 60 41 27.225 N 151 39 23.805 W 2448165.55 203157.91 60 41 26.895 N 151 39 22.793 W 2448130.82 203207.42 60 41 26.565 N 151 39 21.782 W 2448096.08 203256.93 60 41 26.235 N 151 39 20.770 W 2448061.34 203306.43 60 41 25.906 N 151 39 19.758 W 2448026.61 203355.94 60 41 25.576 N 151 39 18.747 W 2447991.87 203405.45 60 41 25.246 N 151 39 17.735 W 2447957.13 203454.96 60 41 24.917 N 151 39 16.724 W 2447922.39 203504.47 60 41 24.587 N 151 39 15.712 W 2447687.66 203553.98 60 41 24.257 N 151 39 14.700 W 2447852.92 203603.49 60 41 23.928 N 151 39 13.689 W 2447818.18 203653.00 60 41 23.598 N 151 39 12.677 W 2447783.45 203702.51 60 41 23.268 N 151 39 11.666 W 2447748.71 203752.02 60 41 22.939 N 151 39 10.654 W 2447713.97 203801.53 60 41 22.609 N 151 39 9.643 W 2447679.23 203851.04 60 41 22.279 N 151 39 8.631 W 2447644.50 203900.55 60 41 21.949 N 151 39 7.620 W 2447609.76 203950.06 60 41 21.620 N 151 39 6.608 W 2447575.02 203999.57 60 41 21.290 N 151 39 5.597 W 2447540.29 204049.08 60 41 20.960 N 151 39 4.585 W 2447505.55 204098.58 60 41 20.631 N 151 39 3.574 W 2447470.81 204148.09 60 41 20.301 N 151 39 2.562W 2447436.07 204197.60 60 41 19.971 N 151 39 1.551 W 2447401.34 204247. tl 60 41 19.641 N 151 39 0.539 W 2447366.60 204296.62 60 41 19.312 N 151 38 59.528 W 2447331.86 204346.13 60 41 18.982 N 151 38 58.516 W 2447297.13 204395.64 60 41 18.652 N 151 38 57.505 W 2447262.39 204445.15 60 41 18.322 N 151 38 56.493 W 2447227.65 204494.66 60 41 17.993 N 151 38 55.482 W 2447192.92 204544.17 60 41 17.663 N 151 38 54.470 W 2447158.18 204593.68 60 41 17.333 N 151 38 53.459 W 2447123.44 204643.19 60 41 17.003 N 151 38 52.447 W 2447088.70 204692.70 60 41 16.674 N 151 38 51.436 W 2447053.97 204742.21 60 41 16.344 N 151 38 50.424 W 2447019.23 204791.72 60 41 16.014 N 151 38 '49.413 W 2446984.49 204841.23 60 41 15.685 N 151 38 48.402 W 2446949.76 204890.73 60 41 15.355 N 151 38 47.390 W 2446915.02 204940.24 60 41 15.025 N 151 38 46.379 W RECEIVED JAN 2 4:- 2001 (3ii & G~.~ Cons. Commission .,perry-Sun Drilling Alas Planning Report - Geographic Fid& COOK INLET S~te: Redoubt ' Wdl: Plan: Redoubt Unit #2 Wel]lmlh: RedouIc~ ~ Co~ordin~e(NE) Reference: Well: Plan; RedOubt Unit ff2~ Grid Nc~lh Vertical (TVD) Re~'eren~e: Plafi: Red~ubtUhit~ 90.0" SecjJon (~'S) Refer'em:e: Well (0.00E,0.00N,125.05Azj) Plan: Redou,bt Unit ft2 Wp2 ~r~ey i?:'?~:: incl ,~im TVD +NI-S +EI-W Northing Easfing Deg Min Sec De~ Mi~ Sec ~N00.~ 37.2~ ~25.05 8~0.~ -3~.46 ~3.25 2~5.~ 2~9.2~ ~ 4~ ~4.~5 N ~5~ ~ ~.~ W ~0.~ 37.2~ ~25.~ 8720.~2 -3~3~.~9 ~2.76 2~0.8~ ~8.77 ~ 4~ ~4.0~ N ~5~ ~ ~.~ W ~0.~ 37.2~ ~25.~ 8799.75 -3~.92 d5~2.27 2~6.07 2~,28 ~ 4~ ~3.7~ N ~5~ ~ 42.~ W 10700.~ 37.21 125.05 ~79.~ -32~.66 4~1.78 2~741.~ 2~187.79 ~ 41 13.376 N 151 ~ 41.3~ W 10800.00 37.21 125.05 8959.03 -3235.40 4611.29 2446706.60 205237.30 60 41 13.046 N 151 38 40,310 W 10900.00 37.21 125.05 9038.67 -3270.14 4660.80 2446671.86 205286.81 60 4t 12.7t7 N 151 38 39.299 W 11000.00 37.21 125.05 9118.31 -3304.87 4710.31 2446637.12 205336.32 60 41 12.387 N 151 38 38,288 W 11100.00 37.21 125.05 9197.94 -3339.61 4759.82 2446602,38 205385,83 60 41 12.057 N 151 38 37,276 W 11200.00 37.21 125.05 9277.58 -3374.35 4809.33 2446567.65 205435.34 60 41 11.727 N 151 38 36,265 W 11300.00 37.21 125.05 9357.22 -3409.08 4858.84 2446532.91 205484.85 60 41 11.398 N 151 38 35,254 W 11400.00 37.21 125.05 9436.86 -3443.82 4908.35 2446498.17 205534.36 60 41 11,088 N 151 38 34.242 W 11500.00 37.21 125.05 9516.49 -3478.56 4957.86 2446463.44 205583.87 60 41 10.738 N 151 38 33,231 W 11600.00 37.21 125.05 9596.13 -3513.29 5007.37 2446428.70 205633.37 60 41 10.408 N 151 38 32,220 W 11700.00 37.21 125.05 9675.77 -3548.03 5056.87 2446393.96 205682.88 60 41 10.078 N 151 38 31,208 W 11800.00 37.21 125.05 9755.41 -3582.77 5106.38 2446359.22 205732.39 60 41 9.749 N 151 38 30.197 W 11900.00 37.21 125.05 9835.05 -3617.51 5155.89 2446324.49 205781.90 60 41 9.419 N 151 38 29.186 W 12000.00 37.21 125.05 9914.68 -3652.24 5205.40 2446289.75 205831.41 60 41 9,089 N 151 38 28,174 W 12100.00 37.21 125.05 9994.32 -3686.98 5254.91 2446255.01 205880.92 60 41 8.759 N 151 38 27,163 W 12200.00 37.2t 125.05 10073.96 -3721.72 5304.42 2446220.28 205930.43 60 41 8.429 N 151 38 26,152 W 12300.00 37.21 125.05 10153.60 -3756.45 5353.93 2446185.54 205979,94 60 41 8,100 N 151 38 25,140 W 12400.00 37.21 125.05 10233.23 -3791.19 5403.44 2446150.80 206029.45 60 41 7.770 N 151 38 24.129 W 12500.00 37.21 125.05 10312.87 -3825.93 5452.95 2446116.06 206078.96 60 41 7,440 N 151 38 23,118 W 12600.00 37.21 125.05 10392.51 -3860.67 5502.46 2446081.33 206128.47 60 41 7.110 N 151 38 22,107 W 12700.00 37.21 125.05 10472.15 -3895.40 5551.97 2446046.59 206177.98 60 41 6.780 N 151 38 21.095 W 12800.00 37.21 125.05 10551.78 -3930.14 5601.48 2446011.85 206227.49 60 41 6,451 N 151 38 20,084 W 12900.00 37.21 125.05 10631.42 -3964.88 5650.99 2445977.12 206277.00 60 41 6.121 N 151 38 19,073 W 13000.00 37.21 125.05 10711.06 -3999.61 5700.49 2445942.38 206326.51 60 41 5.791 N 151 38 18,062 W 13100.00 37.21 125.05 10790.70 -4034.35 5750.00 2445907.64 206376,02 60 41 5.461 N 151 38 17,050 W 13200.00 37.21 125.05 10870.34 -4069.09 5799.51 2445872.90 206425.52 60 41 5.131 N 151 38 16,039 W 13300.00 37.21 125.05 10949.97 -4103.82 5849.02 2445838.17 206475.03 60 41 4.802 N 151 38 15,028 W 13400.00 37.21 125.05 11029,61 -4138.56 5898.53 2445803.43 206524.54 60 41 4.472 N 151 38 14,017 W 13500.00 37,21 125.05 11109,25 -4173.30 5948.04 2445768.69 206574,05 60 41 4,142 N 151 38 13,005 W 13600.00 37.21 125.05 11188.89 -4208.04 5997.55 2445733.96 206623.56 60 41 3.812 N 151 38 11,994 W 13700.00 37.21 125.05 11268.52 -4242.77 6047.06 2445699.22 206673.07 60 41 3,482 N 151 38 10,983 W 13800.00 37.21 125.05 11348.16 -4277.51 6096.57 2445664.48 206722.58 60 41 3.152 N 151 38 9.972 W 13900,00 37.21 125.05 11427,80 -4312.25 6146.08 2445629.74 206772,09 60 41 2,823 N 151 38 8,961 W 14000.00 37.21 125.05 11507.44 -4346.98 6195.59 2445595.01 206821.60 60 41 2.493 N 151 38 7.949 W 14104.93 37.21 125.05 11591.00 -4383.43 6247.54 2445558.56 206873.55 60 41 2.147 N 151 38 6.888 W 14200.00 37.21 t25.05 11666.71 -4416.46 6294.61 2445525.53 206920.62 60 41 1.833 N t51 38 5,927 W 14300.00 37.21 125.05 11746.35 -4451.19 6344.12 2445490.80 206970,13 60 41 1,503 N 151 38 4,916 W 14400.00 37.21 125.05 11825.99 -4485.93 6393.62 2445456.06 207019.64 60 41 1.173 N 151 38 3,905 W 14500.00 37.21 125.05 11905.63 -4520.67 6443.13 2445421.32 207069.15 60 41 0.843 N 151 38 2.894 W 14600.00 37.21 125.05 11985.26 -4555.41 6492.64 2445386.58 207118.66 60 41 0.514 N 151 38 t,882 W 14700.00 37.21 125.05 12064.90 -4590.14 6542.15 2445351.85 207168.17 60 41 0.184 N 151 38 0,871 W 14800.00 37.21 125.05 12144.54 -4624.88 6591.66 2445317.11 207217.67 60 40 59.854 N 151 37 59,860 W 14900.00 37.21 125.05 12224.18 -4659.62 6641.17 2445282.37 207267.18 60 40 59.524 N 151 37 58,849 W 15000.00 37.21 125.05 12303.82 -4694.35 6690.68 2445247.64 207316.69 60 40 59.194 N 151 37 57,838 W 15093.15 37.21 125.05 12378.00 -4726.71 6736.80 2445215.28 207362.81 60 40 58.887 N 151 37 56,896 W 15100.00 37.21 125.05 12383.45 -4729.09 6740.19 2445212,90 207366.20 60 40 58,864 N 151 37 56,827 W 15200.00 37.21 125.05 12463.09 -4763.83 6789.70 2445178.16 207415,71 60 40 58.534 N 151 37 55.816 W 15300.00 37.21 125.05 12542.73 -4798.57 6839.21 2445143.43 207465.22 60 40 58.205 N 151 37 54,804 W 15400.00 37.21 125.05 12622.37 -4833.30 6888.72 2445108.69 207514.73 60 40 57.875 N 151 37 53.793 W RECEIVED JAN ?, ZOO1 Alaska Oil & Gas Cons. Commission ..- perry-Sun Drilling Alask£ Planning Report- Geographic Comlmny: .~ Inlet . ~Ftdd.: COOK INLET site: Redoubt,, Well: Plan: Redoubt Unit Wen~ath: Redoubt #2 ......... Survey Date:. 1112712000. Time: 14:25:58. Page; C~ordi' .~m.~l~.'E)Reference: Well: Platt: Redoubt Unit ~2, Grid North '"' yerl~.~.' ON/D) R~fere~ee: · Fqail: Recl0ubtUnr0f2 o~0.0 Section (¥$) Referenee: Well (0..00E,0.00N,125.05Azi) Plan: Redoubt Unit ~2 Wp2 .................................. Map Map <-=- Lntimde ~ <-- L6nRtmde -==> MD Inel A~im Tgl) +NI-$ +FJ-W Nortbing E~ling Deg Min See Deg Mia ft, deg deg fl ff ft ff ft 37.21 125.05 ' ;12702.00 -4868.04 6938.23 37.21 125.05 12748.73 -4888.42 6967.27 15500.00 2445073.95 207564.24 60 40 57.545 N 151 37 52.782 W 15558.67 2445053.57 207593.29 60 40 57.351 N 151 37 52.189 W 15593.15 37.21 125.05 12776.19 -4900.40 6984.35 2445041.59 207610.36 60 40 57.238 N 151 37 51.840 W Targets · Name De~e'ription.. TVD ' +N/-S '+E/-W Northing East!ng Deg Min. See' ' ' ' .' ' ff ff . ff. ff . ..ff. " . . Redoubt HenhlockTarget 11591.00 -4383.43 6247.54 2445558.56 206873.55 60 41 2.147 N 151 38 6.888 W -Plan hit target Annotation MD TV]) ff ft - 500.00 500.00 800.00 799.88 1100.00 1098.53 1400.00 1393.37 2183.73 2097.22 15558.67 12748.73 Start Dir 1°/100': 500' MD, 500q'VD Start Dir 1.5°/100': 800' MD, 799.86q'VD Start Dir 2°/100': 1100' MD, 1098.53TVD Start Dir 3°/100': 1400' MD, 1393.37q'VD End Dir: 2183.73' MD, 2097.22' TVD Total Depth: 15558.67' MD, 12777.26' 'I'VD REL;E V JAN % ~ 7_001 Alaska Oil & Gas Cons. ,.,u,,,,, Anchorage REDOUBT UNIT #2 CASING DESIGN Setting Depth Size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD Driven 36" Welded 200' Surf. Surf. 200' 200' 18 1/2" 13 3/8" 68g L-80 BTC 3,200' Surf. Surf. 3,200' 2,906' 12 1/4" 9 5~8" 47# L-80 BTC 9,000' Surf. Surf. 9,000' 7,525' 8 %" 7 518" 29.7# L-80 Hydril 521 5,304' 8,800' 7,366' 14,104' 11,591' 6 %" 5 %, 17# L-80 Hydril 521 1,689' 13,904' 11,430' 15,593' 12,776' Casing Joint Strength Body Strength Burst Collapse K lbs K lbs Psi Psi 13 3/8" 68# L-SO BTC 1545 1556 5050 2260 9 5~8" 47# L-80 BTC 1122 1086 6870 4760 7 518" 29.7# L-80 Hydri1521 566 683 6890 4790 5 112" 17# L-80 Hydri1521 338 397 7740 6290 Design Criteria Tension Straight Hook Load - Ignoring Deviation and Buoyancy Burst Full Colum 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. Collapse Full evacuation on the inside backed by expected formation gradient of .45 psi/ft, on the outside. 13 3/8" Surface Casing Tension = 3200' x 68# Rated = 1545 K = 217.6 K Safety Factor = 7.1 Burst = (7525 x .45) - (.10 x 7525') Rated - 5050 psi = 2633 psi Safety Factor = 1.9 Collapse = (2906' x .45) - (.10 x 2906') Rated = 2260 psi - 1017 psi Safety Factor - 2.2 RE. CE VED JAN ~ ~ 2001 Alaska Oil & Gas Cons. Commission Anchorage 9 5/8" Intermediate Casing Tension = 9000' x 47# Rated = 1086 K = 423.0 K Safety Factor = 2.6 Burst = (12776' x .45)- (.10 x 12776') Rated = 6870 psi = 4472 psi Safety Factor = 1.5 Collapse = (7525' x .45) - (.10 x 7525') Rated - 4760 psi = 2634 psi Safety Factor = 1.8 7 5/8" Drilling Liner Tension = 5304' x 29.7# Rated = 566 K = 157.5 K Safety Factor = 3.6 Burst = ((11591 x .4992)+3000)-(11591 x Rated = 6890 psi · 43) Safety Factor = 1.8 = 3802 psi Collapse = (11591' x .45) - (.10 x 11591') Rated = 4790 psi = 4057 psi Safety Factor = 1.2 5 %" Production Liner Tension = 1689' x 17# Rated = 338 K = 28.7 K Safety Factor = 11.8 Burst = ((12776 x .4992)+3000)-(12776 x Rated = 7740 psi .43) Safety Factor = 2.0 = 3884 psi Collapse = (12776' x .45)- (.10 x 12776') Rated = 6290 psi = 4472 psi Safety Factor = 1.4 REGE ¥EO Alaska Oil & Gas ConS. Commission Anchorage i ' 24..],1' , ~L DIMENS~S. ~E APPROX. ii IIll A~e VETCO GRAY' S~MS ENGiNEE~NG ~~~ 36 X 13-3/8 X 9-5/8 X 3-1/2 OD 5,000 MSP MULTIBO~ AsSY ~ V~ ~ PRODUCER ~LL ~DRA,,Y:~ mC' ~A~:11~LY2~ i-FILE ~[FER[NC[, F~R~--Y 'ff. ~A.NGNO. '1 ENG. 'AP~.: AT[: . ~-A ~[: ,A ~RO~CT NO.; SP-4482 IVED Gas Cons. Commission Anchorage Nabors Rig 429 13-5/8" 5000 psi BOP Stack Redoubt Unit #2 5000 psi Annular 3" Kill Line 1 = HCR Valve 2 = Gate Valve 5000 psi Blind Rams I 5000 psi Pipe Rams ~ Mud Cros~>~ 1 2 I 2 1 5000 psi Pipe Rams 3" Choke Line 13 3/8" 5M Wellhead 13-3/8" Surface Casing 9-5/8" Intermediate RECEIVED JAN ?., 4:2001 Alaska Oil & Gas Cons. Commission Anchorage BLOWOUT PREVENTION EQUIPMENT NABORS RIG No. 429 21%" Diverter Equipment 1 ea Hydril MSP 21 ~A" x 2000 psi WP annular blowout preventer 1 ea 21 ~A' 2000 psi WP diverter spool with 16" ANSI 300 outlet flange 1 ea Fabri-Valve Style 36 16" ANSI flanged full port valve with 3000 psi hydraulic operator 1 ea 100' of 16" Sch 40 diverter line 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 11-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. RECEIVED DRILLING FLUID SYSTEM DESCRIPTION 2 4 001 Mud Pumps 2 ea Alaska Oil & Gas Cons. Commission Anchorage 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 REGE VED JAN g 4 2001 Alaska Oil & Gas Cons. Commission Anchorage Redoubt Unit #2 Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE ~/ No abnormal pressures are expected. ~/ No shallow gas expected. Coals will be encountered throughout the Tyonek formation. Tripping speed and mud weight will help alleviate stuck pipe tendencies. Lost circulation is unlikely, however lost circulation potential increases when crossing faults. ~/ H2S has never been encountered in the Redoubt Unit Field. CONSULT THE WELL PLAN FOR ADDITIONAL INFORMATION RECEIVED JAN 2 4 2001 Alaska Oil & Gas Cons, Commission Anchorage 1075 FORCENERGY INC. PH. 907-258-8600 310 K STE. STE. 700 ANCHORAGE, AK 99501 TO THE ORDER OF 4First National Bank of Anchorage ,'00~075,' ~:~5~OOO~=O~: O~l& 89-6/1252 ~ARS [] ........ ~ WELL PERMIT CHECKLIST COMPANY. FIELD & POOL "~ ADMINISTRATION Nn'C ASS AP R WELL NAME/'. 4, / ' -pRoGRAM: exp ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force~. ........... 11. Permit can be issued without conservation order ........ 12. Permit can-be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. '/ dev redrll serv wellbore seg ann. disposal para req GEOL AREA UNIT# ON/OFF SHORE 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. .... 23. If d~ve~er required, does ~t meet regulations .......... 24. Dnlhng fired program schemabc & equ,p hst adequate ..... 25. BOREs, do they meet regulation .... ~'1 ~ ~ ~.~ . . . II&~ peTE 26. BORE press rabng appropr, ate; test to ~~~. os,g: , ~JYI~ ~!~ 27. Choke manifold complies wlAPI RP-53 (May 84). . ...... . . ~ 28. Work w,II o~ur w,thout operat,on shutdown ........... ~ ~. is presence of H2S gas probable ................. II Permit ~n be issued w/o hydrogen sulfide measures ..... "~ ' 31. Data presented on potential overpressure ~one~ ...... ' 32. Seismic analysis of shallow gas zones~'~ .......... APPR DATE , 33. Seabed condition su~ey (if off-shore) ............. ~ ~A 'G"~( 34. Contact name/phone forweekly progress repods [explorato~ A NULA DIS SAL35. W~th proper cemenbng records, th~s plan . (A) will contain waste in a suitable receiving zone; ........ APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: . UICIAnnular COMMISSION: c:\msoffice\wordian\diana\checklist (rev. 11101//00) Comments/Instructions: ' . .~ / ---- , ,O Z O Z .--I -1-