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201-042
slivE • SEAN PARNELL, GOVERNOR 11a�T� ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Hall CEO Cook Inlet Energy 5 = WI aoi 601 W 5th Ave., Suite 310 * Anchorage, AK 99501 Re: West McArthur Field, West McArthur River Oil Pool, WMRU #7a Sundry Number: 311 -169 Dear Mr. Hall: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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 • ate of this letter, or the next working day if the 23rd day falls on a holid,y or eekend. S _ - el; oh. l' ► or. a •mm _ _ DATED this day of May, 2011. Encl. I,JGk , cliip, R Fe c1K7gra , • \I A... At STATE OF ALASKA f t ALASKA OIL AND GAS CONSERVATION COMMISSION :At v : 3 i i ±i b f vt itlf+. r) }iedi55tf01i APPLICATION FOR SUNDRY APPROVALS ', iiC er 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Red❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforatio❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. W❑ Stimulate ❑ Alter Casing ❑ cutoff bottom of tubing tail 0. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Cook Inlet Energy Development Q Exploratory ❑ 201 -042 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 601 W 5th Ave., Suite 310, Anchorage, AK 99501 50- 133 - 20500 -01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No 0 WMRU #7a 1 9. Property Designation (Lease Number): 10. Field / Pool(s): 1 , -e,t_ ADL 359111 ' West McArthur River Field' ' } �i . it, • dr 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): 14,273' . 9,561' . Same Same N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20 ", 129 #, X -56 120' 120' Unknown Unknown Surface 1,987' 13 - 3/8", 68#, L - 80 1,987' 1,967' 3,450 psi 1,950 psi Intermediate 6,536' 9 47 #, L 6536' 5,064' 6,870 psi 4,750 psi Intermediate Liner 6,625' 7 - 5/8 ", 29.7 #, L - 80, 1 ,946' 9,420' 6,890 psi 4,790 psi Slotted Liner 1,462' 4 12.6#, L - 80 1 , 3' 9,561' N/A >6,350' Perforation Dpgth MD ,iic, k Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12,81T- ' Approx. 9,321' - 9420' 2 -7/8" / L -80 12,792' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker S -3 Paker Baker S -3 Packer , 24 ,792y' 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development E. Service El 14. Estimated Date for 15. Well Status after proposed work: 12/2 11 Commencing Operations: Oil 0 - Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact NSachivichik 575 -7156 Printed Name David Hall Title CEO Signature Phone Date /) L� 334 -6745 S////47 4 ��. COMMISSION USE ONLY l 6 •-- c^ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3` ( - I cot Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 1 p — q. 1 i APPROVED BY // Approved by: rir C + MI .TONER THE COMMISSION Date:54 /RIG k: SM AY 162Q/ ' ;� �s , ;4. ,.1, RBDM Form 10 -403 Revised 1/2010 Submit in Duplicate • • _ * Cook Inlet Energy_ RECEIVED May 11, 2011 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 . rI O Re: Sundry Application for Cutting off tubing tail WMRU #7A (PTD No. 201 -042) ;mission 0 rjit & fie$ Dear Mr. Seamount, Cook Inlet Energy recently attempted to pull a tubing plug set at the bottom of the 2 3/8" lower section of well completion of the West McArthur River Unit #7A well. The tubing plug appeared sanded in and the attempt to pull was unsuccessful. Cook Inlet Energy is planning to cut off tubing tail above the 2 3/8" tubing plug to access oil perforations and commence production. . Operations will include running in hole with a jet cutter on e-line, cutting off the 2 3/8" tubing tail with the plug to enable oil production from Hemlock perforations. The Report of Sundry Well Operations includes the following attachments: 1. 10 -403 Sundry Application 2. Brief Operations Summary 3. Current Wellbore Diagram 4. Proposed Wellbore Diagram If you have any questions, please contact me at 334 -6745 or Natasha Sachivichik at SolstenXP at 575 -7156. Sincerely,` David Hall CEO — Cook Inlet Energy 601 West 5 Ave, Suite 310, Anchorage, Alaska 99501 Phone (907) 334 -6745 • • ■ Cook Inlet Energy_ WMRU #7a Wellbore Diagram Current Completion Status (05 -2011) 20" 129 #, X -56, @120' MD, 120' TVD �': * N 1 /4" control line from chemical Injection e: � !c mandrel to surface Y.. .A 13 3/8" 68 #, L -80 BTC, @ 1987' MD, 1967' TVD j )' 1940.74' MD Chemical Injection Item OD ID Top Bottom � �1 mandrel (Length 4.12', ID= 2.347 ", OD=4.335") Sliding Sleeve 3.750 2.310 9940.83 9944.68 2-7/8" EUE Mod Pup 2.875 2.440 6946.22 9956.33 ( 2 7/8" EUE 8 rd tubing to surface X -over sub 3.750 2.440 9956.33 9956.93 V Hydrow 1 Packer 0625 2.908 9956.93 9965.21 y v TOL 7 5/8" @ 6,321' MD X -over sub 4.438 2.440 9965.21 9965.86 ti A l 2-7/8" EUE Mod Pup 2.875 2.440 9965.86 9969.95 9 5/8" 47 #, L -80 BTC @ 6536' MD, 5064' TVD Sliding Sleeve 3.750 2.310 9970.95 9972.52 2 -7/8" EUE Mod Pup 2.875 2.440 997180 9982.03 ' L '�' X-over X-profile nipple 3.250 2.310 9982.03 9983.05 ►�� ■∎� Cement Squeeze perf 5 ea 2-7/8" Blast Joints 3.688 2.440 9983.05 10031.38 4! l 50 its x 2.7/8" EUE Mod. 2.875 2.440 10031.88 11620.48 Gas Perfs @ 9984.5'- 9990.5, 9996' - 10,008', 10,012' - 10,024' Tubing 11 ►� ■ ►Z1 x -over sub 3.76.3 100 11620.4e 11621.09 < 7 -5/8" 29.7 #, L- 80,Hyd 521, @ 12,811' MD 7 -5/8" x 4 EUE Locator 5.00 100 11621.09 11621.50 1096.63' gap between Baker PBR and Seal Assembly w/WLEG 4.00 3.00 11621.50 11621.50 e. Weatherford seal assembly 7.5/8" Black Cat 6.438 4.00 11621.50 11626.58 ``Ic' Item OD ID Top Bottom Retrievable packer . Concentric coupling 5.50 4.00 11626.58 11627.18 ..' Baker PBR 6.47 3.250 12752.50 12764.08 '� A 4 Seal bore Extension 4.813 400 11627.18 11636.60 ..p..• 4 -1/2" Pup x -over 4.5 3.958 12764.08 12769.55 f X - over 325 3.00 11636.60 11637.31 ' Baker S - 3 Packer 6.66 3.958 12769.55 12773.61 X 4.438 2.44 11637.31 11637.96 4 - 1/2" Pup x - over 4.50 3.958 12773.61 12779.57 2 EUE Pup 2.875 2.44 11637.96 11644.26 X - over 5.000 1.992 12779.57 12781.29 XN - Nipple 3.25 2.310 1164426 11645.57 2 - 3/8" Pup 2.375 1.992 12781.29 12786.64 Seal Assembly 1243 2.405 11646.59 11655.87 X - Nipple 2.875 1.87 12786.64 12787.64 2 - 3/8" Pup 2.375 1.992 12787.64 12791.01 Oil Producing Zone 2 - 3/8" Mule Shoe 2.875 2.125 12791.01 12791.70 4-1/2" 12.6 #, L-80 IBT Slotted Liner . MD, 9,561' TVD r�scss._ • • • Cook Inlet Energy_ WMRU #7a Wellbore Diagram Proposed Completion Status Mg P :% 20" 129 #, X -56, @120' MD, 120' TVD � i�.% ;» 1 /4" control line from chemical Injection mandrel to surface 13 3/8" 68 #, L -80 BTC, @ 1987' MD, 1967' TVD ;f 1940.74' MD Chemical Injection Item OD ID Top Bottom ` mandrel (Length 4.12', ID= 2.347 ", OD= 4.335 ") Sliding Sleeve 3.750 2.310 9940.83 9944.68 2- 7 /8 " EUE Mod Pup 2.875 2.440 9946.22 995633 ( 2 7/8" EUE 8 rd tubing to surface X -over sub 3.750 2.440 9956.33 9956.93 4.. VV Hydrow 1 Packer 6.625 2908 9956.93 9965.21 ✓, y y V TOL 7 5/8" @ 6,321' MD X -over sub 4.438 2.440 9965.21 9965.86 ✓; 2 -7/8" EUE Mod Pup 2.675 2.440 9965.86 9969,95 ✓ 9 5/8" 47 #, L -80 BTC @ 6536' MD, 5064' TVD Sliding Sleeve 3.750 2.310 9970.95 9972.52 2 -7/8" EUE Mod Pup 2.875 2.440 997280 9982.03 'l.'u' X-over X-profile nipple 3.250 2.310 9982,03 9983.05 ►►►►�� � � Cement Squeeze perf 5 ea 2.7/8" Blast Joints 3.688 2.440 9983.05 10031.38 41 l 50 its x 2.7/8" EUE Mod. 2.875 2.440 10031.88 11620.48 Gas Perfs @ 9984.5'- 9990.5, 9996' - 10,008', 10,012' - 10,024' Tubing , I II ►1: �� X -over sub 3.750 3.00 11620.48 11621.09 < 7 -5/8" 29.7 #, L- 80,Hyd 521, @ 12,811' MD 7.5/8" x 4 EUE Locator 5.00 3.00 11621.09 11621.50 = 1096.63' gap between Baker PBR and Seal Assembly w/WLEG 4.00 3.00 11621.50 11621.50 r' ."4 Weatherford seal assembly 7.5/8" Black Cat 6.438 4.00 11621.50 11626.58 Item OD ID Top Bottom Retrievable packer ;V/ �� • • Concentric coupling 5.50 4.00 11626.58 11627.18 1 "'�;� Baker PBR 6 .47 3.250 12752.50 12764.08 Seal bore Extension 4.813 4.00 11627.18 11636.60 ' y .' * 4.12" Pup x -over 4.5 3.958 12764.08 12769.55 • I' , j I X -over 6.25 3.00 11636.60 11637.31 Baker S-3 Packer 6.65 3.958 12769,55 12773.61 X -Over 4.438 2.44 11637.31 11637.96 Cut point 4-1/2" Pup x -over 4.50 3.958 12773.61 12779.57 2 -7/8" EUE Pup 2.875 2.44 11637.96 11644.26 X -over 5.000 1.992 12779.57 12781.29 XN- Nipple 3.25 2.310 11644.26 11645.57 2 -3/8" Pup 2.375 1.992 12781.29 12786.64 Seal Assembly 3.243 2.405 11646.59 11655.87 X - Nipple 2.875 1.87 12786.64 12787.64 2 - 3/8" Pup 2.375 1.992 12787.64 12791.01 Oil Producing Zone 2 - 3/8" Mule Shoe 2.875 2.125 12791.01 12791.70 4 -1/2" 12.6 #, L -80 IBT Slotted Liner 14,273' MD, 9,561' TVD • West McArthur River Unit #7A Tubing Cutoff Procedure 1. Rig up e -line equipment on WMRU -7A. z 2. RIH to bottom, tag fill on top of the tubing plug. 3/ Plug above the fill. 4. Correlate and tie in. 5. Cut tubing at agreed depth below the Baker S -3 Packer . 6. POOH out the jet cutter. 7. Rig down e-line. 8. Turn well over to production group. 4 • • S EFATE 0[F icasEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 333 W. 7th AVENUE, SUITE 100 II CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Hall CEO Cook Inlet Energy ao i- 0_________.42 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: West McArthur River Field, West McArthur River Oil Pool, WMRU #7a Sundry Number: 311 -100 AvAtilIED APR 0 4 Z01 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 holi. , , or weekend. Sincere ,• i for •.v t . issi. er DATED this 1 day of April, 2011. Encl. • • Cook Inlet Energy_ RECEIVED 29 2011 March 29, 2011 Alaska Oil IAR & Gas Cons. Commission Mr. Dan Seamount, Chair Anchorage Alaska Oil and Gas Conservation Commission 333 West 7 Ave., Suite 100 Anchorage, Alaska 99501 Re: Sundry Application for Coiled Tubing Cleanout WMRU #7A (PTD No. 201 -042) Dear Mr. Seamount, Cook Inlet Energy is planning to perform coiled tubing fill clean out in their West McArthur River Unit #7A well. Operations will include removing a fill on top of the tubing plug and pulling the tubing plug out to enable oil production from Hemlock perforations. The Report of Sundry Well Operations includes the following attachments: 1. 10 -403 Sundry Application 2. Brief Operations Summary 3. Current Wellbore Diagram If you have any questions, please contact me at 344 -6745 or Natasha Sachivichik at SolstenXP at 575 -7156. Since y, David Hall CEO — Cook Inlet Energy 601 West 5 Ave, Suite 310, Anchorage, Alaska 99501 Phone (907) 344 -6745 ' 1444k- • C�J" • RECEIVED f 1 STATE OF ALASKA .ef' je , ' tl ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Hoke x'11 a Gas Con Cwnulission 20 AAC 25.280 yi' »oihfge 1. Type of Request: Abandon ❑ Plug for Red❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program 0 Suspend ❑ Plug Perforatio❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. W❑ Stimulate ❑ Alter Casing ❑ Coiled Tubing Cleanout 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Cook Inlet Energy Development El • Exploratory ❑ 201 -042 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 601 W 5th Ave., Suite 310, Anchorage, AK 99501 50-133-20500-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number. property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El WMRU# l a , 9. Property Designation (Lease Number): I 10. Field/Pool(s): b;/ Ac,/ ADL 359111 • West McArthur River ye{d" , P -3 r i 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): 14,273' + 9,561' • Same Same WA WA Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20 ",1298, X-56 120' 120' Unknown Unknown Surface 1,987' 13 -3/8 ", 68e, 1.80 1,987' 1,967' 3,450 psi 1,950 psi Intermediate 6,536' 9-5/8 ", 478, L-80 5,064' 6,870 psi 4,750 psi Intermediate Liner 6,626' 7-5/r, 29.78, L-80, 1 ,946' 9,420' 6,890 psi 4,790 psi Slotted liner 1,462' 4- 1/2",12.68, L-80 14,273' 9,561' WA >6,350' Perfora' n Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12,81 ' - 14,273' Approx. 9,321' - 9420' 2-7/8" 1-80 12,792' Pack SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 121 Welk- Baker 5-3 Paker Baker S-3 Packer 12112" l' 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4110/2011 Oil El • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ p GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact NSachivichik 575 - 7156 Printed Name David Hall Title CEO Signatu `J Phone 344679.5 Date 3 `/ COMMISSION USE ONLY 2 Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3' k -1 00 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. Subsequent Form Required: `Q _ 4 0 4 . APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: RBDMS APR 0 4 2011 3.3/•!/ RIGI�I Form 10-403 Revised 1/2010 Submit in Duplicate • Cook Inlet Energy_ WMRU -7a Coiled Tubing Fill Cleanout Summary Procedure 1. Mobilize coiled tubing unit to WMRU pad. • 2. Check for pressure on the wellhead. Bleed off gas from tubing and annulus if any. 3. Fluid pack the tubing and annulus with produced water. 4. Rig up the coiled tubing equipment. 5. Test CT BOPE to 3000 psi. 6. RIH with coiled tubing and cleanout BHA to the top of fill. 7. Pull above the fill top and start circulating and washing down according to procedure provided by coiled tubing service company. 8. Clean the fill out down to top of the prong and plug installed 12787 "MD. Monitor pressure and the string weight at all times. 9. After reaching planned TD, pull out of hole while circulating. 10. Rig down coiled tubing equipment. 11. Rig up slickline and run in hole to pull out the prong and the and the plug. 12. Install production tree. Turn over well to production crew. I Cook Inlet Energy_ WMRU #7a Wellbore Diagram Current Completion Status 20" 129 #, X -56, @120' MD, 120' ND '� V % y ►► i: i ;� ,�♦\ 1 A" control line from chemical Injection i`3: i . i \�� %A mandrel to surface ti 13 3/8" 68 #, L -80 BTC, @ 1987' MD, 1967' TVD %,Ii _ % • IS 1940.74' MD Chemical Injection Item OD ID Top Bottom mandrel (Length 4.12', I13= 2.347 ", BgdklgNesve 1756 2.310 wan sus OD= 4.335 ") 2-7/8" EUE Mod Pup 2.271 2140 6956.72 6556.55 ✓, < v 2 7/8" EUE 8 rd tubing to surface Xover sub x760 2.140 9956.33 9908.99 ✓ : • v NVdraw 1 Packer 1825 2106 906693 9966.21 7i; y� TOL 7 5/8" @ 6,321' MD X sub 4430 2.440 9966.21 9965.66 V. \ \• 4, • •v • 2.7/ 8 " EUE Mod Pup 2.575 2.440 99611 990139 :ij .' 9 5/8" 47 #, L -80 BTC @ 6536' MD, 5064' TVD Ming Shwa 3.793 2416 9471198 wan 2.7/8" EUE Mod Pup 2.175 2.440 9973.00 999213 ,I:i1J X•overX•profllenipple 1250 2.310 996203 9963.05 4 ►�� ........11 Cement Squeeze pert 4! I _ C sea 2.7/8" Bleat Joints 290 x 614 991.90 10671 2.440 I . t 50 n3. x 2.7/8" EUE Mod. 2.876 2.440 10081.60 11690.44 = -• - Gas Pads @ 9984.5'- 9990.5, 9996' - 10,008',10,012' - 10,024' Tubing llii Xover Sub x760 3.00 90 00 11620.14 11621. 6 l�it � ►.7161 < 7 -5/8" 29.7 #, L- 80,Hyd 521, @ 12,811 MD 7.5/8" x 4 EUE Locator 6.00 3.00 11621.09 11621.50 NB `.. 1096.63' gap between Baker PBR and Seal Aaaembyw/WLEO CO 3.00 "62'.60 7257.1 ;�� . v Weatherford seal assembly >`v. ■ v 7alB' Black Cat 1691 490 1313190 11023.68 ; ♦ v. M. • � � • Item OD ID Top Bottom �• op R84ktnONpa y �,� �� ,\� ConCCntllC coupling 6.50 100 11626.93 11127.13 �J Baker PBR 13. x266 1729x60 12764.06 N. . v Seal bore Extension 1113 400 11627.16 1163160 jj \.% 4.1/Y' Pup rover 15 x961 12764.08 12769.56 Xover 625 3.00 1163160 11637.31 a Baker 8-3 Packer 190 3.901 1271695 127191 X.°ver 4435 2.44 11637.31 1163718 4-112" Pup xover 4.50 3.968 12773.91 12719.67 2 - 7/8" EUE Pup 2.515 244 11637.96 11644.21 Xovar 6.000 1.992 12779.57 12701.29 XN•NIpple 3.25 2710 1154429 11646.57 2,1/8" Pup 2.375 1.902 12781.n 1279164 Seal Assembly 3.243 2405 11646.59 11656.97 X - Nipple with plug 2075 1137 1271164 12737.114 2-316" Pup 2375 1192 12787.64 12791.01 Oil Producing Zone -• --)* • 2,318" Mule Shoe 2.575 2.125 12311 12711.79 4 -1/2" 12.6 #, L -80 IBT Slotted Liner 14,273' MD, 9,561' ND J NS 07 270 0 • ~ Page 1 of 1 Regg, James B (DOA) From: Brad Rasch [Brad.Rasch@fepsi.com] ~ ~ ~ ~ ~~ Sent: Thursday, June 03, 2010 10:29 AM I' ~ !~ To: Regg, James B (DOA) Subject: Update Mr. Regg, Letting you know we did land our completion string for WMRU #7A on 6-2-10 at 1800 hrs. We got good tubing and casing tests after landing out completion. Regards Brad Rasch ~ j f`'t~1 6/3/2010 2nl n~Z Aulxrt, Winton G (DOA) From: Natasha Sachivichik [natasha.sachivichik~fepsi.com] Sent: Monday, May 17, 2010 3:48 PM To: Aubert, Wrnton G (DOA) Cc: Etill Penrose; David Hall Subject: WMRU 7A Re-completion plan Rev.S Attachments: WMRU 7A Re-completion plan Rev.5.doc Winton, • Page 1 of 1 As discussed earlier in the phone conversation, Cook Inlet Energy is planning to run a single 2 7/8" completion in WMRU # 7a for Cook Inlet Energy. The current plan is proposing a different completion configuration from previously submitted in the sundry application. Could you please review the attached updated procedure and the wellbore diagrams and let us know if we can get an approval to proceed with the proposed plan or if we need to provide any additional information. Many thanks, 7latao<ra Sactk Senior Drilling Engineer Office: 907.264.6116 Cell: 907.575.7156 natasha.sachivichik@fepsi.com i ` e. 5/1912010 r~ i West McArthur River Unit #7/~ V.14~- Well Re-Completion Workover Procedure °~ ~ ~ r d 1. Pre-Rig Operation 1. l Mobilize personnel and equipment necessary for pre-rig operation. 1.2 Rig up Pollard Slick Line and pull the jet pump and standing valve. Monitor the well. Reservoir pressure is approximately 2,500 psi (based on WMRU#5 static pressure measurements) and the hydrostatic head of a full column of produced water will be 4120 psi { 9320'(TVD) x 8.5 x 0.052) so the fluid level in the well is expected to fall. The maximum calculated surface pressure is 2300 psi. 3 Set a tubing plug in X-nipple (ID= 1.87" profile). RD slick line. 4 Circulate the well conventionally with 8.5 ppg produced water. Continue circulating until all the crude oil is removed. 5 Bundle test the well to confirm casing integrity to 1500 psi for 15 min. Record on a chart. 6 Install 2-118" BPV in the tubing hanger. 7 Remove the flow lines from the well head. 2. Rig Operation 2.1 Rig up AWS #1 over the well. Nipple down the production tree. 2.2 Nipple up 11"SM x 11" 3M DSA, 11" 3M mud cross and 11", 3M BOP stack (annular, blind rams, 2-7/8" pipe rams). PuII the BPV and set a two way check valve. Test BOP's to 3000 psi. Notify AOGCC at least 24 hours before testing BOPE. After testing the BOP pull the two way check valve. 2.3 Circulate the well through ports on jet pump cavity and be prepared to capture any remnant crude oil in the returns. Circulate Super-slick (J313 pill} to help tubing pullout. 2.4 Since the tubing plug is set in the tubing below the packer, no losses are expected until the packer is milled out. 2.5 Rig up E-line unit, tubing cutter, RIH and cut the tubing at 12,790' MD. (Note: record the top of the 7-5/8" liner during the wireline run) 2.6 Pull 2-7/8" L-80 tubing. LD tubing. Monitor well for fluid losses. • 2.7 Set wear bushing. • 2.8 P/U 6-3/4" Type MM packer mill and milling BHA with a mud motor and pump-out sub on 2-7/8" work string for milling out and retrieving Baker Model S-3 packer set at 12,792' MD (Note: 7-5/8'~ casing has 6.875" ID). 2.9 TIH to top of the packer at +I2,792'MD. 2.10 Establish all string weights before milling packer per BOT packer milling procedures. Mill the packer. 2.11 Monitor fluid losses, reporting them to the Anchorage office when a stable value is obtained. If losses are relatively small, proceed with the workover, filling the hole periodically with additional produced water. If the fluid loss rate is too high to keep up with for the length of the work over, mix a 40-bbl HEC pill, feed it into the tubing as the level drops then continue following it with produced water. When the HEC pill reaches the perfs, the fluid loss rate should decrease. Note: See Attachment 1 for mixing HEC Pill and Attachment 2 for mixing Flowzan sweep. l~'hen the hole is stable add J313 to reduce metal to metal friction. 2.12 After packer falls, circulate bottoms up with caution, then chase packer to the top of 4.5" liner 12,811'MD. Circulate bottoms-up again. Drop the ball and open pump-out sub. POH. LD milling assembly. 2.13 PJLT Baker fishing tool with pump-out sub on 2-7/8" work string and RIH to retrieve Baker S-3 packer. 2.14 POH with packer. 2.15 Run a tandem 9-518" and 7-5/8" scraper to top of 4.5" liner at 12,811'. Space out the scrapers so the 9 5/8" scarper reaches the top of the 7 518" liner at 6321' MD. Circulate the well clean. Use sweeps as necessary 2.16 Displace well to 9.8ppg produced water for balancing the gas zone to be perforated. 2.17 Monitor well for any changes in behavior. POH. 2.18 Rig up wireline. • i M/U and run new 7 5/8" packer with X-nipple with tubing plug and wireline entry guide below. The top of the packer will have a Seal Bore Extension and one joint of 2 7/8" tubing. RIH w/ packer assembly on a-line. Note: Fill the tubing tail above the tubing plug with viscous gel fluid (Provided by Weatherford) to prevent arty perf debris from entering the seal bore extension 2.19 Set packer in the middle of a full joint of 7-518" liner at ±12,790'. 2.20 Pressure test the wellbore and packer to 1000 psi for 15 min. Record the pressure test on a chart. 2.21 M(T 3-318", perforating guns, 6 spf gun, RIH and perforate the 2 intervals at 9,996' - 10,008' and 10,012- 10,020' NID. POOH, LD perforating equipment. RD a-line. 2.22 Perform a cleanout run to remove perf debries down to the tubing plug to remove the protective gelled fluid from the plug top. 2.23 Pull wear bushing. 2.24 M/U the following assembly and run to the top of the packer: The final completion diagram will be attached to the procedure. The items below will be part of the completion: • Seal assembly • Bottom sliding sleeve • Top 7-5/8" packer • Top sliding sleeve • Jet pump cavity. • 2-7/8" tubing • 2 718" Chemical injection mandrel and'/4" stainless steel tubing. 2.25 Circulate packer fluid to be from top of the bottom 7-5/8" packer to tubing hanger as per B.J. Chemical Service. 2.26 Sting into the seals assembly of the bottom packer. Observe string weight loss. 2.27 Pull up to the rig floor, space out and install the tubing hanger. Pressure test and terminate the chemical injection line at the tubing hanger. R1H and land the tubing hanger with the 2 7/8" stung into the lower packer correctly. • 2.28 Set the top 7-5/8" top packer at calculated depth. 2.29 Run in the lock down studs and pressure test the tubing hanger seals with Vetco Gray. 2.30 Pumping on back side, pressure test upper packer to 1400 psi for 30 minutes. Record the test on a chart. 2.3 i i est 2-7/8" tubing to 3000 psi against the tubing plug set earlier. 2.32 Install BPV and ND the BOPE. 2.33 NU the production tree. 2.34 Pull BPV. Install 2-way checks into the tubing hanger_ Pressure test the tree to 3000 psi. 2.35 Remove the 2-way check valve. Install BPV. 2.36 Release the rig. Attachments: 1. HEC pill preparation sheet 2. Flowzan pill sheet 3. Current well completion diagram 4. Proposed well completion diagram • Attachmentl ~ M-1 L.L.C. HEC Pil! G~_ ~riF' ~~~ Input HEC pill for losses to perforations F:luu '..'e .~h`_ _. 4 Output - i bbl - =r_~•~.:t°s ~:ancen:-atio- err =~Id.. Ib La~.~. ,_a..r,. F~I:i. ~~b f_.~~~. rY.i t rl ~.~II ~.r.•~:•~ath 1 otil~• t •-:r~t~r _. f I x ~.~ ~ al_~,s _ - HF ~ ~ •~,:t,~ i^^^t ~i ~~r_~t~ ic~r t=~ rni-u ~ ~r:ru ~ v~r -. ='u~rF: ~ r-s_ ~ ~r~ i~t^ 'o~~ ~an~. ='u' ~ F 3•,~:a =-~~~ - r~= ~c~ _ . f•1 x r: ri •~~ ~~ _ ~:, - :ri~#fectie Total '" - .~~ `I~,J ;~- _ Caloulaied Mud Weight ~ ~` _,f Recornmenda#ions for fosses in perfora#ions: TI?e f° ~t ~~h~l ~.; r~~,,r~irn==~d+~~ is 5c~ ~~r ~I~ r.-in ~.5 ;~~h HEC. T~-is ~.~ 3houlcl k~e rrna~:e~ .~ '~~ r~ i~r{ :: it. f~~or7.toy the ~Fft'r=iQneS oftne orl =,e. 4 BPH Ioss~ _~~~~~s~;t tc 2~ BPHi Wrior to ~,rcle~eJ`=~~ :o tFe ;~rcont? c:~ro^. If ~:h~ p'li is partial{}~ eftrfti •~, ~~ .~ iri?r ,~rn~?ir,g an 'le~~tic ~I ;~iG. ;tke ~~re>.c° Lr:°~ p`II ~ec;:rrn?~~c~ i arJt~~er ~~ ii~..rre ~ cif 2.~ apf~ HEr=-ld. hr1~^rito: ~~=e ~~fe,_ ~~~nrss s~f t~~? r' t~ :lct~-rn'n? if an a:llit c~~ l;'ll :s ::~~°-rart~. 1-~ ti'`r;~i CC.ty" PryIII;Ir C't'c''ilt't~ art"i c1(~}~?-1s~c•.,ii rc'CGrn`!lt"';.~eC~i i5 5,n ;'.ar='E'i5 ,7' li`.: ~~ ~'e'.'itll ~.u~ p}:~ HEC and -tC' pti~ Sa~~t a"1; ~~r ~,ir~ -i~at~=~~-~ . • • Attachment 2 MUDCALC 4.5 -Water-Based Mud Calculation M-I L.L.C. 1 n nut C~es~rintion FIL,r~art ~i'C #or I:~ses '~ {:~i ~rali~3~~s ~it~d ~~'v`ei~ht ~. output -1 bbf ~- Pr~~3ucts <~:~rceniraticr•. ~~c~luma F#ef~i_ iL LAG. a~~~ Fielu_ l>~( =~t,. ,ml •.~px~L~tµr '„t.~ u../I ~a 1~i .' i. {)~~ '.~h"r~. ~I "?bl 1._t t Ntt Yp<th =+'~f f;bl ~:t ~;~ater. ~~ ,~ ~: -=' s~4~kv :~t -ivy:=r~~i ~L~:~ ~r ti~.t?~ ~.~er ~~:c.h: ir~u ait. n.~,l~it? for {~ ntirates _ "ur`~!~ a~~r:~ss per=~ iii .~ 14~s_. ~<:r~e P~if ~~ yr trsf:ins F3ri` _ ~ Ices =`~~F- =~. ~,lsx ;ill ~ ;see t~l :;; if i~tf'e<t=, 'otai :aict otal Mud ~'~.I _ ^2 Recamrnendatiansfnr sweep: 1. If'csse ~r~ st~:~iecl art cl~.~~ eat pii; pci~~~d~ rrsix 1 ~i:~ -' sf~~•~ ~•oti r~ €hru hcp~~~ (2i' Attachment 3. C'Qmpletic~n eat c.~thur Rimier knit ~A. given C;~-r~d.~G#t Sutt"~r~ C~Sirty 1~ 112"" kiole 9 ~`8" ~7#. L-Std BTU fntcrm~i~tc Casi~c 'i + 1i4" H~rIP 7 5t8' 2~.7#. ~-$D Fiy 52 4rt~rtY`edi~k+~ i.et-er ~ 1 fit" Hem t f f f ! E 4 1 ! 4 1 B 7 A 1 F 3 B ~ € S3c~tted ~r~t~et~on Lltler ~ 6 3~4" HCie , ~,~- ~.. ~y C~ 'I.987 R~1C3 - 1.'367' '~!Q 6.x•:36' fJ{t:1 - 5,{64` 1`VD i c~cc~ .fete-~~rn~ - 12, 72~#' C} 13ake~ M~ciel S-:~ Pa~Ker - 1:2,792 N'C3 t_s~er Tc~p - 12.8" ' ` MEt1 • Attachment 4 Existing Completion BHA as Run ,~,:~_ :I , ~ ~.~..~_ - - ~~,~ ~; ,: ~ ~~ ~_ ~~ . .. ~ ,I ~ ,. h.r :~C R. .~, .~.L,~f t . c c:_ .:1~ ~,. .' ~: 433ij~ f . S t` s ~~ ,t ~ j r ~.. ~ ~ ~_ ~_ ps ~ ~S.} 1 r L~~ - .. iU ~ itl ~ .~...._ .__.... ~.. .~t~ . . , i ~ . . = p . ~ ,. ~~ . . v . ~.. . ~~ , ' ~ F } ~ ~ __ d SC' ~~3te ~ ~.F ._- 4 .ors tkCi fQ ~ ' l `i'; 1ti. - .... ~..e ..~.._y._ Rr rx.E ,~._._~~_ - _.F St . '> { ref r e_eT ~. _ __..~_...__~~..~.. _._.._.______._.._._..- - _ _ ~ ~_!~~ • S n~ G~ ~'taS3`E? >t? l.! ~ ~ F'o ~ HJ{s'.j `58~ ....,.. _ ~-A iiE f +$' r. ~. C~FJ 2 1 °..~. Y)F{ t,.4T1i :3Q X .7 t=~.t /~--' ~, q ~ # cr 31~ ~. ~.. Ge eu; '.~~ ~ "l R iL`~.iKtSF °i <ra:. k>? xp4 -~ ~ ~ ~ _e~ ,. >~..,__-___-j~ . :S Z%t > f c.`s: t : .'.S~h <! ' ~ F D }~`` ~ ~'i.eX h f i-'.F` 13 t~ "_~_ ~iv ` t ~ ~ 'i 3 Mr;,9 1 } ~v~ ~ f_ F'uSi ~'.~ . ' _._.s ___ ___ _ _ __ -^-- t ~ ~ tF'~4~?t= fit. ;.i°•~,-... , 4~Fv ,C. ?iT .,3 5i.ii ;{ ~~ Attachment 5 ~?4"MRLT ~7a Proposed Single Completion a 193'' P•rt~. 9~E7 T!;'C G 5,8. rt;T.-8C BTU ~a E536~ Pv1G. 50E~' T!r'G Gas Ferfs c ~.99~ -1v.~.,~~8 . 1v.C1~ - 10.v2v 2 ?:8" x 7-5: ~~° PacKer :~. 12.?92 P:1~ f -5'0 ~8?=. _-8i;.-iya ~~~?. ° 12.0' 1 t.9G -1 2' 12 6" L-3u It3T Slo;tec ~:r,er 2x00 ~.1D Chemical In;ec;~en manarel ~' ~~• tUUI'~a J.iVV -0L ; :% g' :a: 6.321 P:1u _et Fump ~~av=; Slidna Slee•,e -1 Sllft7 ~ICCVC I - _ 3..0.5=. L-33~ by I (~ I I I I G I = rc;:uc rg %cre I I I I - - - I 1.2'3 f.1C. ~•.c6i :-D L • • David Hall CEO Cook Inlet Energy, LLC 4141 B Street, Suite 302 Anchorage, AK 99503 2- ~a~~~~ Re: West McArthur River Field, West McArthur River Pool, WMRU#7a Sundry Number: 310-147 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 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. s ~~~~;_ y .; r~, ._ ~E~ DATED this ~ 7/day of May, 2010. Encl. Cook Inlet Energy_ May O5, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval Re-completion of WMRU #7A (PTD No. 201-042) Dear Mr. Seamount, ~ RECEIVED MAYQ62010 •Dq~,~ommi~ion ~n Cook Inlet Energy plans to work over the West McArthur River Unit #7A well. Operations will include removing the existing Ingle oil completion, perforating a new gas zone and re- completing the well with a , a1~.~0'mpletion to produce both the oil zone and the gas zone separately but simultaneously:'--'" During the workover, Cook Inlet Energy will be opening a new gas producing interval at ±8,500' MD. Pending a successful production test of this interval, we intend to pursue gas sale contracts for the production. Aurora Well Services Rig #1 (AWS #1) will be used to perform this workover. The following attachments are included in this application: 1. 10-403 Application for Sundry Approval 2. General Workover Procedure 3. Current Wellbore Diagram 4. Proposed Wellbore Diagram WMRU #7A is currently undergoing a flow test evaluation of the Hemlock oil zone and will be shut in to accommodate the workover upon approval of this application. If you have any questions, please contact me at 677-6799 or Natasha Sachivichik at Fairweather at 264-6116. Sincerely, ~~ ~~~ David Hall CEO -Cook Inlet Energy 4141 B Street, Suite 302, Anchorage, Alaska 99503 Phone (907) 677-6799 or 317-8239 STATE OF ALASKA (~y~l't~ ~~ ALAS~IL AND GAS CONSERVATION COMMISS~ . APPLICATION FOR SUNDRY APPROVALS ~~~ ~R1AY 0 6 2010 ~° 20 AAC 25.280 f ~,, OS~!~LA f0 6;. a~~~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Re-en ' Alter casing ^ Repair well ^~ ~ Plug Pertorations ^ Stimulate ^ Other ^ Sp Change approved program ^ Pull Tubing [V~ WGI, Perforate New Pool ^~ Time Extension 2. Operator Name: 4. Current Well Class: .Permit to Drill Number: Cook Inlet Energy, LLC Development 0 , Exploratory ^ 201-042 - 3. Address: Stratigraphic ^ Service ^ .API Number: 4141 B St., Suite 302, Anchorage, AK 99503 50-133-20500-01- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ~ ^ ~ WMRU#7a- Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 359111 West McArthur River Field/ est McArthur River Pool 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): 14,273' - 9,561' ' Same Same N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20", 129#, X-56 120' 120' Unknown Unknown Surtace 1,987' 13-3/8", 68#, L-8o, BTC 1,987' 1,967' 3,450 psi 1,950 psi Intermediate 6,536' 9-5/S", 47#, L-8o, Brc 6536' 5,064' 6,870 psi 4,750 psi Intermediate Liner 6,625' 7-s/8•', 29.7#, L-8o, Hyd 527 12,946' 9,420' 6,890 psi 4,790 psi Slotted Liner 1,462' 4.112•',12.6#, L-8o lBT 14,273' 9,561' N/A >6,350' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12,811' -14,273' Approx. 9,321' - 9420' 7718" ! L-80 12,792' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (f Baker S-3 Packer 12,792' Bak 12. Attachments: Description Summary of Proposal Q 3. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory^ Development ^~ - Service ^ 14. Estimated Date for 'I'SO Well Status after proposed work: Commencing Operations: 5/15/2010 Oil 0 _ Gas WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Natasha Sachivichik 575-7156 Printed Name David Hall Title CEO Phone Signature Date ~ ~ GL~ 677-6799 COMMISSION USE ONLY i i f l N if i i th t t ti C C N b ~~ ~ "~ ("f it S d ond t ons o approva : ot y omm on so a a represen a ve m ss un um er: ry ay w ness Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other. ~ ,e S~ ~ ~ ~) C {'Q '3 D O O ~ S G . Subsequent Form Required: (~ APPROVED BY ~~ /~ ~ ~~ D t Approved by: a e: STONER THE COMMISSION RBDMS MAY 12 1010 Form 10-403 Revised 7/2009 OR161NAL Submit in Duplicate nPPROXIM lE MFAN 2 MLC / ~ ~ ~P~ :~EIA WATER LIN ~ P' '~1Aa; o r' m ` ~ ~ ~~= o A/61 V. :f. WE S? MCARTHUR RIVF4 UNIT o `% SwONf ~ ~~L 1„"`°;~~ ~` i~ReoNC a MEV ~ ~ 1 o U~OCON PW ~P~~ 60 p00NG PO 4 WI\E a C C I E nE ~ laE A PN 30 S 9 ~U ~ teJ`P~ 0 U~ E _ F / ~ C ~ ` PWE~ - ~5 ~ ~ ~ ~ o ISO ~ PN ~ s~EO R~1 ~~ ~ ' ~ ~ f ~ '~ ° E° PT ~` EH I°,~ A I eoG ~a e ~ o ~mQ E , S 0 ^E ~ K1tCNEN P O VYING 0 FS c NPOp II ~j 6A HD S P i~ EOG PP (\/ \ ~p E,0. O ~_ I rc n EEN~ J 0065 / ~ ) i cE T xISTINC ono c~G` ~`K~ ~ ~ F \ oe O POWER ABLE TO C Q ra E5 / ~ '~ ~ ° P \ y.~ / / ~ '' PCCE 5 POAO i0 KPF Q ~ ~ \ ~ C/] D ~~' ~ ~ F n CGES ROPE ~ EMENT ~ ~ ~ Q nT5 CO P DENTE' VNE 60 E ~ ~ ~ ~ v a ° I / i ~ \ ~ ~ASEMEN\ ~H ~ L¢ o i ' AGE 6O~ ~ \ H \ Oll EgSE o \ ~ ~~ ' , ~ 9 DTAM MENT ~ ` \ ~ O q m i i o i i ~ ~ f+ \ , ' "O EASE ENT \ ~..1 Q' \ i/// / ` / i ' ~ EO/ 5fi 0\PM. GAS \ ~ W o . // ~ c~, \ ~ ~ ~ i C4yF ,~ / \ \ I F,^,w ~NfRD 1 w U g('AQp ~ \ NE 60 EP M WEST MCA.4 THUR RIVER UNIT WELLS Oil F~sc^ ,~ \ GENTERV WMRU 1A 9y. \~.J \ F 1 S grey \ \ GRID N_2482928.566 W aqM ~ 1 9 ~~ ~ TA j~ ~(NE \ GRID E:187279.870 4< ~ ~ o ~~ ~ ~N 48~ \ TYPICAL PIPELINE RELATIONSHIP LATITUDE: fi O'a7'USO53" aD XO \ LON GI7UDE` -151'45'00.175" ~ \ ~ I ~ ~ \ THIS SHEET WMRU 2A P(''1'fs G / \\ AFTER WMRU GRID M2492962902 a'f ~ °_ / \ GRID E:187346.567 ~,~, I m ~ \ LATITUDE: 60'47 Oq.424" MFN2 ~ ~ NOTE3~ LONGITUDE: -151'44'58.797" I C ~m \ wMRU Da wELL TIPICAL PIPELINE RELATIONSHIP ~ III U m x 1) BA515 OF COORDINATES IS FROM THE CONTNUOUSLY OPERATING REFERENCE STATON KENt NEAR KEN ALASKA. Gkl9 N: 2482118.058 THIS SHEET \ (O c~ci pam COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE NAD 27 ZONE 4. ~ GR:D -_:187849.021 Nl~ j BEFORE WMRU ~ ~. ~ ~~° 2) BEARINGS SHOWN ARE GRID ANO ARE Bg5E0 ON REPEATABLE GPS OBBERVATONS BETWEEN THE 2 INCH \ LATITUDE'. 60'46~57.224~~ G~ M F ALUMINUM CAPPED MONUMENTS SET NEAR T1E BLUFF ONE ON EITIER SIDE OF THE PIPELINE ALIGNMENTS NHERE \ LON GITJO~~: -151'44'48.301" ~ ~ '~ THEY CCME ON SHORE FROM TiE OSPREY PLATFIX2M. \ ~P '(N~ O - 3J STATIXJINC SHOWN HEREON IS BgSEO ON THE ASBUILT LOCATION OF TIE B" OIL l1NE CONSTRUCTED IN 2002. \ WMRU b5 WELL ~ ~ Z'~Q' ~J am^ STATONING BEGINS AT 1HE WESTERN MOST LEC OF THE OSPREY PLAIFIXtM (STATON 0+00) ANO CONTNUES TO \ GRID N:2482059.713 ~ V ~aa TIE NIX21H BOUNDARY OF UNITED STATES SURVEY NO. 4520 gMENOEO (MOSQUITO ALLOTMENT). \ GRID E:187659.464 4j EASEMENT CENTERLINE BETWEEN THE MHNL OF COOK INLET ANO TIE NEST MCARTHUR FACILITY SHOWN HEREOfI `~ LA IITUDE' 6G'46~5I.046~~ \ 17 - IS NOT BASED ON ANY PIPELINE CENTERLINE, BUT WAS PLACED 50 THAT PLL REWIRED PIPELINES WOULD FALL nOgF ~ LONGI tUDE: ~-151'44~4H.060" ~ ~~\~h XQO \ ~ \\ NITMIN THE EASEMENT 1NOTH. FROM THE NEST MCARTHUR FACIVTY NORTH TO THE NORTH BOUNDARY OF UNITED STALES SURVEY N0. 4520 AMENDED, TIE 60' EASEMENT SHOWN HEREON SHARES ITS EAST EDGE NITI TiE \ WMRU 6A G N \ ~ E%ISTNG 1995 20' CIRI EASEMENT. 1HEREFORE. IT LIES DIRECTLY ADJACENT qNO WESTERLY OF 1HE E%ISTNC 1995 GRID N: 24H2942.469 w CIRI EASEMENT. \ G _ E-1P' '.5 ~P'p~ 5) DISTANCES BHONN HEREON ARE CRIO. \ LATITUC ~~-fi~~ '~P ~ DRAWN BY MSM 6H THE PROPERTY BOUNDARIES SHOWN HERON WERE NOT RETRACED IN 1HE FIELD DURING THIS SURVEY AND ARE \ S \~' OWN FOR INFORMATONAL ANO COMPUTATONAL PURPOSES ONLY. 1HE LINES SHOWN HEREON flEPRESENTNG T1E \ ''~ONGITL~~. -151'4` J.4Fi3~~ BEGINNING ANO TiE ENO OF 1HE EASEMENT DESCRIPTONS AT BOT1 CENTERLINE AND EDGE OF EASEMENT SHALL BE - \ \ CHECKED RV HORTENEO TO TERMINATE OR BEgN qT THE TRUE PROPERTY eOUNpARIES WMRU' 7i )) SECTIXJ LINES SHOWN HEREON ARE PROTtACTED. \ GRID N: e.82949.48L` HORZ. SCALE I" 200' BJ SURVEY CONDUCTED BY MCLANE CONSULTNG CROUP DURING CONSTRUCTON OF PIPEVNES DURING SUMMER \ GRID F.'.137259.512 2002. \ \ LATINDE. 60'4] 05.254" VERY. SCALE I" _ 9) TIE FIRER OPTIC LINE INSTALLED IN 2002 IS NOT SHOWN GRAPHICALLY HEREON AND ITS LOCATON WAS NOT \ LONGITUDE: -.St'4v 00.596~~ ORWG. NO. 043056 20 PHYSICALLY LOCATED. FROM T1E BORE SITE TO FOREST OIL FEE PROPERtt (STATION 94+47 i0 STATON 152+02) \ THE FlBER OPTC LINE WAS INSTALLED BETWEEN 1HE B" OIL UNE ANO THE 6" GAS ONE. GROM FOREST OIL FEE ROPERTY HEADING NORTH TO NEST FORELANDS R1 PAO (STATON 224+2} TO STATON 3Z0+00) TIE FIBER OPTC c~p~Tf l' T~~ti1~TO1mf oI.T S H E E T LTHE 1RApINC BATEPRODUCTON TFACILITY (STATON 3D0+OOR OA 60~l+o S) 1HE FlBER 0 TIC LINE WAS INSTALLEOTO \ \ JPA.IIGN aµ LVW1l\01"11! of\, RANGE 14W BETWEEN THE 6" cqs uNE AND THE e" DIL uNE. \ SURFACE OR'NERSHIP SAIAMATOF NATIVE ASSOC. i \ \ SUBSURFACE RIGHTS CIltI I West McArthur River Unit #7 Well Re-Completion Procedure 1. Pre-Rig Operation 1.1 Mobilize personnel and equipment necessary for pre-rig operation. 1.2 Shut -in the well and bleed off gas head in 2-7/8" tubing and 9-5/8" x 2-7/8" annulus. 1.3 Fill tubing and annulus with produced water. Have extra water on location for fill up. Reservoir pressure is approximately 2,500 psi (based on WMRU#5 static pressure measurements) and the hydrostatic head of a full column of produced water will be 4,052psi (9320'(TVD) x 8.36 x 0.052) so the fluid level in the well is expected to fall ~ ~ ?~ ` `t ~f 1.4 Insta112-1/8" BPV in the tubing hanger. 2. Rig Operation 2.1 Rig up AWS #1 over the well. Nipple down the production tree. 2.2 Nipple up 11"SM x 11" 3M DSA, 11" 3M mud cross and 11", 3M BOP stack (annular, blind rams, 2-7/8" pipe rams). Test BOP's to 3000 psi Notify AOGCC at least 24 hours before testing BOPE. 2.3 Pull BPV. 2.4 RU pollard Slick line and pull jet pump (located at 12,724' MD) to surface. Circulate well with J313 to reduce metal to metal friction. 2.5 Monitor fluid losses, reporting them to the Anchorage office when a stable value is obtained. If losses are relatively small, proceed with the workover, filling the hole periodically with additional produced water. If the fluid loss rate is too high to keep up with for the length of the work over, mix a 40-bbl HEC pill, feed it into the tubing as the level drops then continue following it with produced water. When the HEC pill reaches the perfs, the fluid loss rate should decrease. Note: See Attachment 1 for mixing HEC Pill and Attachment 2 for mixing Flowzan sweep. • 2.6 Rig up E-line unit, tubing cutter, RIH and cut the tubing at 12,790' MD. ~ 2.7 Pu112-7/8" L-80 tubing. LD tubing. Have Weatherford hand inspect and redress jet pump as necessary. Monitor well for fluid losses. Pump another 40 bbls of HEC pill if required. 2.8 Tubing hanger inspection redress and tree inspection to be conducted by VetcoGray on site. 2.9 Secure the well (plug down-hole ei~ermer~ ~. S-t. ~ ~'t-h 2.10 Change out the tubing spool as needed. 2.11 Set wear bushing. 2.12 P/U 6-3/4" Type MM packer mill and milling BHA with a mud motor and pump-out sub on 2- 7/8" work string for milling out and retrieving Baker Model S-3 packer (Note: 7-5/8" casing has 6.875" ID). 2.13 TIH to top of the packer at ±12,792'MD. 2.14 Establish all string weights before milling packer per BOT packer milling procedures. Mill the packer. 2.15 After packer falls, circulate bottoms up with caution, then chase packer to the top of 4.5" liner 12,811'MD. Circulate bottoms-up again. Drop the ball and open pump-out sub. POH. LD milling assembly. 2.16 P/LT Baker fishing tool with pump-out sub on 2-7/8" work string and RIH to retrieve Baker packer. 2.17 POH with packer. 2.18 Run 9-5/8" scraper to top of the 7-5/8" liner at 6,321' 2.19 Run 7-5/8" scraper to clean 7-5/8" liner from 12,600'MD to 12,811'. ~' 2.20 Displace well to 9.4 ppg NaCI brine for balancing the gas zone to be perforated. ~ 2.21 Monitor well for any changes in behavior. ~'~a .~c~C9~~1)~~3~~~ 2.22 M/LT and run new 7 5/8" packer with X-nipple and..~nd wireline entry guide below. The top of the packer will have a Seal Bore Extension and ie~joint`of 3.5" tubing. RIH w/ packer assembly on a-line and set packer in the middle of a full jo~rit`of 7-5/8" liner at ±12,790'. POOH. 2.23 Run tubing plug after setting the packer in order to p-test 2.24 Pressure test the packer from the top to 1000 psi for 15 min. 2.25 Pull the tubing plug. 2.26 MU 3-3/8", perforating guns, 6 spf gun, RIH and perforate the gas interval at ~!~MD. POOH, LD perforating equipment. RD a-line. 2.27 Pull wear bushing. 2.28 M/U the completion assembly and run to the top of the packer according to Weatherford recommendations. 2.29 Balance tubing every 500 feet. 2.30 Commence pumping slowly down the annulus; take returns out the tubing as the seal assembly approaches the packer. Observe the pressure increase as the seals enter the packer and shut down the pump. Stack out 30K lbs on the packer to ensure it is set properly. 2.31 PU on the tubing to neutral weight at the packer and calculate space out pups needed. 2.32 Set the 9-5/8" dual packer following Weatherford recommendations). 2.33 Pumping on back side, pressure test packer and seal assembly to 1000 psi for 30 minutes. 2.34 Space out the seal assembly and tubing hanger as per Weatherford program. 2.35 Run the tubing hanger into position and run in lock down studs. 2.36 Install BPV, 2.37 ND BOP, NLJ production tree. 2.38 Pull BPV. Insta112-way check into the tubing hanger. P- test the tree to 5000 psi. 2.39 Remove the 2-way check. • 2.40 Drop the standing valve in the hole and follow it to the seat with the standing valve shifting tool on Pollard slick line. Set down and confirm standing valve is in place. 2.41 Release AWS #1 rig. Completion ~~~ 12~#, [7rivea~, Gonductar 9ao~ rya - ~~~° Q ~ ~ ~~ sa#~ ~.-sa ~Tc sUrt~ce c;~,~ A ~L r~ ~~~'Pe i.~/I.A~ ~~Y L-54 8TC Int~rmediete Casing 12 1 ~4" Hobe f i7/S7~ +Get7. l ~~ L°~G7rV ~C tntermerii~e Liner 8112° Halo i i i i i i r ~ i i r t ~ i ~ 4 1~2" 12,~i#, L-80 ~BT i i Slatted Production Lire' fi ~~4" Hate ~ ~7C7! IVI~ ° E'I ~ 1 Y~ 1.~I~~tiMl~ I~i~.f "' ~s~ ~ Y IJ Tf ~VV ~~41 ~.Al l l~ {,~1~+~F Bel(~tr Mori s-~ Pacice~r - 12.,792' Ala[3 Liner Tap - 12.,5'! 1" ~d 12,946' MCA 9,42q' Ta/C1 WMRU #7a Proposed Completion 20" 129#, X-56, @120' MD, 120' TVD 13 3/8" 68#, L-80 BTC, @ 1987' MD, 1967' TVD ~ 9-5/8" Dual Packer for 3.5" and 2-3/8" tbg ~ ~ 2-3/8" L-80 Tbg Tail @ 6,400' MD ~ 9 5/8" 47#, L-80 BTC @ 6536' MD, 5064' TVD ~ Trico Jet Pump on 2" Coil tubing ~ ~ Standing Valve on 2" Coil tubing tail ~ 7-5/8" 29.7#, L-80,Hyd 521, @ 12,811' MD TOC @ 6,321' MD Packer @12,972' MD 3.5", 9.3#, L-80 tbg ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Oil Producing Zone ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4-1/2" 12.6#, L-80 IBT Slotted Liner ~ ~ 14,273' MD, 9,561' TVD • • From: Saltmarsh, Arthur C (DOA) Sent: Monday, March 09, 2009 11:08 AM To: Maunder, Thomas E (DOA); Seamount, Dan T (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); McMains, Stephen E (DOA); Williamson, Mary J (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); Colombie, Jody J (DOA); Gary Carlson; Norman, John K (DOA); Foerster, Catherine P (DOA); Laasch, Linda K (DOA); longmere@verizon.net Subject: FW: Pacific Energy files chapter-li, it's official!!! FYI. PACIFIC ENERGY RESOURCES LTD. 111 West Ocean Blvd., Suite 1240 Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter 11 to Facilitate a Restructuring a_o ~ - ova,. 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 deft. In connection with the filing, the Company is seeking customary authority from the Bankruptcy Court that will enable it to continue operating its business in the ordinary course of business. The requested approvals include requests for the authority to make wage and salary payments and continue various benefits for employees. In addition, the Company has negotiated a commitment for $40 million in debtor-in-possession ("DIP") financing. The DIP facility wraps and replaces two of the Company's three asset-based credit facilities and is being provided by the lenders of the two credit facilities that are being replaced. Upon Court approval, the DIP financing combined with the Company's operating revenue will provide sufficient liquidity to fund working capital, meet ongoing obligations and ensure that normal operations continue without interruption during its restructuring. About Pacific Energy Resources Pacific Energy Resources Ltd. is an oil and gas exploration and production company based in Long Beach, California, U.S.A. Additional information relating to the Company may be found on SEDAR at www.sedar.com. The Company's web site is www.PacEnergy.com. ON BEHALF OF THE BOARD OF DIRECTORS • PACIFIC ENERGY RESOURCES LTD. Pacific Energy Resources Ltd. 310 K. Street, Suite 700 Anchorage, AK 99507 Office: 907-258-8600 Fax: 907-258-8601 David Hall Alaska Operations Manager Main: 907-868-2133 Cell: 907-317-8239 dmhall(a~.pacenerQy.com www.pacenerQY com e e .....~.-- .'...,; - ... MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc STATE OF ALASKA ALl )A OIL AND GAS CONSERVATION COM. ASION REPORT OF SUNDRY WELL OPERATIONS R'ECEIVED 'NO V 102005 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator Forest Oil C()rporation Name: Repair Well ~ Pull Tubing D Operat. Shutdown D Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D 3. Address: 310 K St,Ste 700, Anchorage, AK99501 7. KB Elevation (ft): 163 8. Property Designation: ADL-359111 11. Present Well Condition Summary: Total Depth measured 14,273 feet true vertical 9,561 feet Effective Depth measured 14,273 feet true vertical 9,561 feet Casing Length Size MD Structu ral 120 ft 36" 120 ft Conductor Surface 1831 ft 133/8" 1831 ft Intermediate 6986 ft 95/8" 6986 ft Drilling Liner 6715 ft .75/8" 12946 ft Production Liner 1462 ft 51/2" 14273 ft Perforation depth: Measured depth: Slotted liner SCANNED DEC 1 !i 2005 True Vertical depth: Slotted Liner Tubing: (size, grade', and measured depth) 27/8" 6.5 # N-80 Packers and SSSV (type and measured depth) 12792' Pkr 12. Stimulation or cement squeeze summary: Intervals treated (measured): Slotted Liner Treatment descriptions including volumes used and final pressure: 950 bbls of 1 Oo~ HCI and 25 % Xylene 13. Alaska Oil & Gas Cons. Commissio~ Stimulate ~ Other U Anchorage Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: S~ploratory D;~. 201-042 . . $ervice D' 6. API Number: 50-133-20500-01 9. Well Name and Number: WMRU #7 A 10. Field/Pool(s): West McArthur River Field/ West McArthur River Pool Plugs (measured) Junk (measured) TVD Burst Collapse 120 ft 1818 ft 5362 ft 9423 ft 9570 ft RBDMS BFL NOV 1 4- 2005 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 26 1292 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. Prior to well operation: Shutin Subsequent to operation: 110 14. Attachments: Copies of Logs and Surveys Run no Daily Report of Well Operations yes Contact 'kd. irCt-~ y- Printed Name Paula Inman /') /} P Signature f~~4~' 35 2300 Service D GINJ 0 WINJ 0 WDSPL Sundry Number or NIA if C.O, Exempt: ~105'- I ~tj o Title Production Engineer Phone 868-2137 Form 10-404 Revised 04/2004 ORIGINAl Date 11/8/2005 Submit Original Only N ) ) Forest Oil Corporation WMRU # 7 A Coil Tubing Workover July 15, 2005 0600 hrs Weather =56 degrees, overcast BJ services Coil Tubing Unit # J195 Day # 1 Report from 0600 hrs. July 15TH, to 0600 hrs. July 16th, 2005 Went over (teleconferenced) revised WMRU # 7 A clean out procedure with BJ supervisor Will Gaulding and Roto Jet tool hand. Weaver Bros. equipment operator Rob King arrived at 1030 hrs, went through orientation, began building barge ramp for 15t barge due in tonight at 2300 hrs. Finished welding 24 mill. Liner together and build berm around Well # 7. Clean, transport and set 2 - 220 bbl open top tanks one in a secondary containment at Pad # 5 and the other inside a secondary containment at WMAC. Received the Red Dog barge at 2345 hrs, off load 3 - Rain for Rent tanks and Nitrogen bulk tanks. July 16, 2005 0600 hrs Weather = 60 degrees, partly cloudy BJ services Coil Tubing Unit# J195 Day # 2 Report from 0600 hrs. July 16TH, to 0600 hrs. July 1ih, 2005 Transport barge loads, (3 Rain for Rent tanks, the WBI float trailers with Nitrogen bulk tanks) from the barge ramp to WMAC and spot in place. Clean out the 2 open top tanks using Unocal Super Sucker Vac truck, repair ware and suction Butterfly valves on tanks. Removed flow line from WMAC # 7 A and installed a 2 1/16", 2" ported flange with swing 1502 flow back line off the wing valve. BJ Coil tubing crew scheduled to arrive at 1730 hrs and Red Dog barge # 2 call out at 2100 hrs at OSK was postponed due to incident described below. WMAC # 7A C.T. project postponed until BJ Coil Tubing services can regroup / recover their equipment to continue with the project. Sent Weaver Bros. operator and UOSS roustabouts to town. July 17, 2005 0600 hrs Weather = 64 degrees, clear BJ services Coil Tubing Unit # J195 Day # 3 Report from 0600 hrs, July 17TH, to 0600 hrs. July 18th, 2005 BJ C.T. Services worked on the electrical systems on their Nitrogen and fluid pumps, test ran for 45 minutes (good test). Located additional HCL in Anchorage and will be in route on Monday. Received word from Phil Rafferty that they are planning to be ready to barge Monday evening with all their equipment ready to go. July 18, 2005 0600 hrs Weather = 57 degrees, cloudy BJ services Coil Tubing Unit # J195 Day # 4 Report from 0600 hrs. July 18TH. to 0600 hrs. July 19th, 2005 BJ services received the additional HCL acid needed to perform the clean out process. BJ C.T. crew, Weaver Bros operator and UOSS roustabout arrived at 1820 hrs. Went through WMAC orientation, waste management, road rules and Unocal facility speed limits. Scheduled barge call out at OSK for 2300 hrs. Red Dog barge # 2 arrived at Trading Bay at 0300 hrs. Off loaded 2 "Rain for Rent" tanks, Coil Tbg. Unit, pumping units, choke manifold, flow back iron and ops. Cab. July 19, 2005 0600 h rs Weather = 54 degrees, overcast BJ services Coil Tubing Unit # J195 Day # 5 Report from 0600 hrs. July 19TH, to 0600 hrs. July 20th, 2005 Tail gate safety meeting with BJ services, WBI operator and UOSS roustabouts. Extend liner and berm footprint, begin spotting tanks and C.T. equipment. Prep for Barge # 3 backloads. Begin filling Frac tanks with fresh water, make up flow back iron from production tree wing valve to choke manifold. Rig up BOPE, make up to riser and injector head. Gave AOGCC 24 hrs notice to test BOPE. Jim Regg waived witnessing the test. Received Red Dog barge at 1700 hrs. Off load HCL, Xylene bulk tanks, (placed HCL into a secondary containment on Pad # 5 until time to be blended). Nitrogen bulk tanks, mixing unit, pallets of Soda Ash and Sodium Bicarb and WMAC dumpsters. Back load WMAC full dumpsters and empty oil totes. July 20, 2005 0600 hrs Weather = 55 degrees, clear BJ services Coil Tubing Unit # J195 Day # 6 Report from 0600 hrs. July 20TH, to 0600 hrs. July 21th, 2005 Tail gate safety meeting with BJ services, WBI operator and UOSS roustabouts. Extend liner and berm footprint for centrifugal pump and filter skid. Continue to fill Frac tanks with fresh water. Begin rolling I blending KCL total volume = 950 bbls. Add additives and inhibitors in preparation to blend in Xylene and 35% HCL (acid). HCL, liquid additives, xylene, fresh water = 16,100 total gallons with 10% HCL and 25% Xylene, 8.775 ppg. Titrate tests by BJ rep Dave Cope. Prepare to and filiI pressure test hard lines, choke manifold valves, 4 1/16" stripper component and Coil tbg. BOPE from 200 psi to 3000 psi. Perform BOPE Accumulator pressure I time test. E-mailed BOPE test report to AOGCC. State witnessing of BOPE test was waived by Jim Regg as reported on yesterday's A.M. rpt. July 21,2005 0600 h rs Weather = 52 degrees, fog BJ services Coil Tubing Unit # J195 Day # 7 Report from 0600 hrs. July 21 TH, to 0600 hrs. July 2ih, 2005 Tail gate safety meeting with BJ services, WBI operator and UOSS roustabouts. Reviewed WMRU # 7 A clean out procedure. BJ Coil Tech tool Rep Bruell Rollins and I confirmed that the Roto Jet shifting 3/8" steel ball (painted yellow) would drift through upper BHA and disconnect sub and seat properly into the Roto Jet sleave. Verified that the ~" ball (painted orange) would ) ') seat properly into the disconnect sub. C.T. Supervisor Will Gaulding in possession of the 2 shifting steel balls. Make up BHA, pressure test riser connection. Open Production tree, break circulation. 1130 - 1530 hrs: RIH with 1.75" Roto Jet assy. At Min. circ rate of X bpm KCL fluid 1530 -1630 hrs: Attempt to pass through 1.87" 1.0. "X" nipple at 12815' C.T. depth, no go 1630 - 2009 hrs: POH 2000 - 2200 hrs: wipe down BHA observed metal shavings around magnetic filter sub, possibly from C.T. running in hole. Secure well and C.T. equipment. Baker oil tools motor head assy. and 2" step mill will arrive at 0730 hrs July 22, 2005 0600 hrs Weather = 57 degrees, clear BJ services Coil Tubing Unit # J195 Day # 8 Report from 0600 hrs. July 22TH, to 0600 hrs. July 23th, 2005 Tail gate safety meeting with BJ services, WBI operator and UOSS roustabouts. Baker Tools Motor head assy. and 1.90" step mill arrived at 1230 hrs. Strapped I callipered BHA, drifted steel balls (7/16" and %") for disconnect and circ sub, Make up, pulled test BHA. Pres. Test bonnets and lubricator. Open up well 1330 -1700 hrs: RIH at min. pump rate of ~ bpm, shut down pumps at 12723', (no rotation through Trico pump cavity), continue in the hole at % bpm rate. 1700 -1830 hrs: Tag up at 12797, 18' above yesterdays tag. We tagged bottom of Baker S-3 Packer, XIO from 4 %" x 23/8". Attempt to pass without pumps, no go. Attempted to rotate mill through 12797', 5 mud motor stalls in 1 hr. total Mill time 6 % mins. 1830 - 2200 hrs: POH, no rotation through Trico pump cavity with mud motor. Observed main hydraulic pump mounts working loose, POH slowly and monitored 2200 - 0100 hrs: Break off 1.90" mill, observed normal wear pattern, possibly some marks indicating pulling out of restriction. Work on C.T. hydraulic pump, retapped bolts and anchor down. Secure well and C.T. equipment July 23, 2005 0600 h rs Weather = 56 degrees, partly cloudy BJ services Coil Tubing Unit # J195 Day # 9 over all Day # 3 actual well work Report from 0600 hrs. July 23TH, to 0600 hrs. July 24th, 2005 Tail gate safety meeting with BJ services, WBI operator and UOSS roustabouts. 1.75" Taper and 1.80" Pineapple mill arrived 2130 hrs July 22nd. Make up Pineapple mill with motor head assy, BOPE shell pressure test, open well. NOTE: We have not observed returns when circ down C.T. string on yesterdays round trip in the hole and today, as of 1300 hrs the well has taken 400 bbls of KCL, we will continue monitoring hole volume 0800 - 1130hrs: RIH at 1/4 bpm pump rate 1130 - 1230 hrs: Pass through previous tight spots at 4 %"X 2 3/8" cross over at 12797' and "X" nipple at 12815' with out observing C.T. string taking weight or over pull, pass through several times each. 1230 - 1430 hrs: Continue RIH at X bpm pump rate, check pick up weight at 50' and 25' intervals, no over pull. Tag 4 %" Liner T.D. at 14277' motor stalled at T.D. for first time this trip. 1430 -1800 hrs: POH, dress "X" nipple at 12815' at 1 bpm pump rate through mud motor and mill and cross over at 12797' 5 times before continuing out of hole 1800 - 1830 hrs: Remove injector from well, lay down mill I motor assy. (normal wear on mill), make up Rota Jet assy. Prep for tomorrows "Stimulation Procedure". Secure well and C.T equipment. July 24, 2005 0600 h rs Weather = 57 degrees, rain BJ services Coil Tubing Unit # J195 Day # 10 over all Day # 4 actual well work Report from 0600 hrs. July 24TH, to 0600 hrs. July 25th, 2005 Tail gate safety meeting with BJ services, WBI operator, WMAC production crew and UOSS roustabouts. Reviewed "Well Stimulation Procedure". Pressure test BOPE bonnet, open well head and line up valves for circulation down C. T and returns to pit. 0730 - 1100 hrs: RIH with 1 %" Roto Jet tool assy. at min pump rate of % bpm and 200 scf/min of Nitrogen 1100 - 1230: Passed through 4 %" X 2 3/8" cross over at 12797', attempted to pass through "X" nipple at 12815', no go. Increased pump rate to 1.5 bpm, 2ndattempt was successful. Continue to RIH at min pump rates, tag 4 %" liner TO at 14277' 1230 - 1300 hrs: Begin "Well Stimulation Procedure": pump 5 bbls of inhibited water, 52 bbls of one-shot plus Acid 1300 - 1430 hrs: POH at 25 fpm laying acid pill across the 4 %" slotted liner to 12850', (35' below "X" nipple) 1430 - 1500 hrs: Allow acid slurry to soak across the liner 1500 -1600 hrs: RIH with 1 bpm 1400scf/min pump rates to 14277'. Pump 5 bbls of inhibited H20 and Acid slurry atTD. 1600 - 0000 hrs: POH pumping acid slurry with 305 bbls of slurry left in tank at 14 fpm to make 2 full pass through slotted liner from 14277' to 12920' (top of slots at 12946'), continue with pumping schedule as per procedure 0000 - 0115 hrs: Prep C.T to and drop dual circ sub 3/8" ball followed by 5 bbls of KCL, at 1 bpm, pump 400 scf/min Nitrogen 0115 - 0530 hrs: Ball seated in circ sub and shifted sleave to open 45 degree upward jets, begin POH from 14277' to end of completion string at 10 fpm scouring 4 %" slotted liner. Wash through Trico pump cavity to clean seat. POH at 100 fpm to surface continuing jet wash with dual circ sub. 0530- 0600 hrs: Out of hole, break off Roto Jet assy. secure well and C.T equipment July 25, 2005 0600 hrs Weather = 53 degrees, cloudy BJ services Coil Tubing Unit # J195 Day # 11 Report from 0600 hrs. July 25TH, to 0600 hrs. July 26th, 2005 NOTE: after strapping frac tanks, calculations show that the WMRU # 7 A took 250 to 275 bbls of KCL/HCL. Safety meeting with BJ services, WBI operator, WMAC production crew and UOSS roustabouts. Prep to Demob BJ C.T. Unit and equipment. Disconnect I drain up hoses and hard lines, break down secondary containment. Prep C. T. equipment to load out on WBI trailers and stage at barge landing for back load to OSK. Begin transferring loads of spent HCL slurry from open top tank and 500 bbl frac tank to Pad # 5 open top tank for disposal down injection well. Rig up and test Swaco electric injection pump. Make up WMRU # 7 A tree cap flange. Consolidate fluids into single 500 bbl Frac tank, prep Osprey hard line basket with all components tallied and ready for Barge. 4 - BJ reps will be leaving this A.M. back to Kenai. 2 BJ reps staying to over see transferring loads to barge ramp ') ) July 26, 2005 0600 hrs Weather = 54 degrees, cloudy BJ services Coil Tubing Unit # J195 Day # 12 Report from 0600 hrs. July 26TH, to 0600 hrs. July 2ih, 2005 Safety meeting with BJ services, WBI operator,and UOSS roustabouts. Set I bind down loads on WBI trailers, clean out open top return tank with Unocal Super Sucker truck (3 hrs). Nipple up WMRU # 7 A power oil flow line to Production tree. Transfer 135 bbls of KCL from frac holding tank to fluid return frac tank. Build secondary containment around 500 bbl fluid return frac tank. Begin transferring loads from the fluid return 500 bbl tank to Pad # 5 injection tank and begin injecting Work Over fluids. Transfer 4 Rain for Rent tanks to barge ramp. Make up barge "Back Load" manifest # 1 for tomorrow A.M. Red Dog barge (E.T.A. 1030 hrs). Swaco electric injection pump developing leak around liner sleave, redressed fluid end of pump. Continue with injection down Pad # 5 D-4 well. July 27,2005 0600 hrs Weather = 55 degrees, overcast BJ services Coil Tubing Unit # J195 Day # 13 Report from 0600 hrs. July 27TH, to 0600 hrs. July 28th, 2005 Pump off all standing water I contaminates on liner with Vac truck, roll up and store liner and felt. 2 - Pollard reps arrived at 0830 hrs, rig up and set "Standing Valve" into WMRU # 7 A completion string "Trico Pump Cavity". Perform bundle test at 900 psi. Rig up and drop Jet Pump into Trico Pump Cavity. Place WMRU # 7 A on line at 1400 hrs. Sent to town: 1 - UOSS operator and 1 - BJ Coil Tech rep with 2 Pollard Wireline reps. Prep WBI trailer loads and "Back Load" Manifest for 2nd barge. Red Dog barge arrived at 2245 hrs, off loaded WBI trailer with empty "Used Battery" tote, 4 empty "Oily Waste" and "Contaminated Dirt" pallet boxes, misc. totes of lubricants and totes of Production chemicals. Back load barge with BJ Coil Tbg units and tanks. The last of the Coil Tbg. Project crew will be going at 0900 hrs. July 28th. Observed high temperature at gear end of the Swaco electric injection pump at 1730 hrs, shut down pump. Danny Neal (Mechanic) will look at it today. This report concludes the WMRU # 7A Work Over. Well7A restart 7/27/05 rigged up pollard wireline @ 0900 hrs performed JSA @1 030 hrs with production and wireline crews. greased all valves on tree with pnuematic grease gun @ 1045 hrs. started downhole wI standing valve @ 1050 hrs. shook standing valve off wireline at 4900' depth @1115 hrs. ran out of hole and rigged down pollard lubricator @ 1215 hrs. started circulating down tubing @1250 hrs at 2.7 bpm. shut in circulation returns @ 1320 hrs and pressured up to 900 psi. held pressure for 15 minutes and showed a shut in pressure of 860 psi. dropped pump into tubing @ 1345 hrs and maintained a p.o. rate of 3.0 bpm. reduced p.o. rate to 2.0 bpm at 55 bbls. ( tubing volume= 74 bbls.) pump seated @ 1405 hrs. increased p.o. psi to 2500 psi and monitored. ," ~;i,i [Æ/A\ TI'Œr' 1 I' I!JJ I I . ~ I Ll í ~ U i ) rm:E I,! I ì ~ F \~ U ) f!~' Ii ,r-'J. /--~ íl' ~,.. /'7,1 i /i \ !: i I \ I, ru t I, ; I ;:~ ~ f/,8 \ , I ¡ ¡ l\,\ l, "'l3~'\,\ I r,,' / !J \ Ln I, " II l'-n i) III UA \) Ln, \1 u U L...::::íJ i l,j \~~ : I \.1 u u FRANK H. MURKOWSK/, GOVERNOR A.I,ASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Kramer Production Manager Forest Oil Corporation 310 K Street Suite 700 Anchorage, Alaska 99501 J,.O I_Dlþ~ SCANNED JUL ~~ () 2005 Re: West McArthur WMRU 7A Sundry Number: 305-194 Dear Mr. Krumer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on 0 }day or weekend. A person may not appeal a Commission decision to Superior oud unless rehearing has been requested. DA TED thislC day of July, 2005 Encl. 07/15/2005 18: 54 FAX 907 258 8~01 FOREST OIL ALASKA c.p;r ']..If> ...O~ l4I 002 i ) STATE OF ALASKA ) 0ECE\VED ~( ALASKA OIL AND GAS CONSERVATION COMMISSIOIf' '5 l<:( APPLICATION FOR SUNDRY APPROVAL JUL 1 ß zoo, 20 AAC 25,280 . Cðmmiillt'Øn Operational shutdown U perforate'~ka ai\ & ~,~. ," ' Other U Plug Perforations 0 Stimurate~ Time E~Me Perforate New Pool D Re-enter Suspended Well 0 4. Current Well Class: 5. Permit t~1 Number: Development 0 Exploratory 0 201-042 Stratigraphic 0 Service 0 6. API Number: 50-133-20500-01 ./ 1. Type of Request Suspend U Repairwell 0 Pull Tubing D Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Forest Oil Corporation 3. Address: 310 K Street Suite 700, Anchorage Alaska, 99501 7. KB Elevation (ft): 163' KB 9. Well Name and Number: WMRU 7 A 8. Property Designation: 10, Field/Pools(s): I ADL-359111 West McArthur River Field / West McArthur River Pool 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): 14,273 9,561 Same N/A N/A Casing Length Size Burst Collapse Structural N/A Conductor 120' 20" 129# X-56 UNK UNK Surface 1,987' 13·3/8',68#, L-ao BTC 3450 1,950 Intermediate 6,536' 9·5/8",47#, L·ao BTC 6870 4,750 Intermediate Liner 6,625' 7-5/8",29,7#, L·80, Hy 521 6890 4,790 Slotted Liner 1,462' 4-1/2", 12,6#, L-ao 18T N/A >6,350 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):: 12,811 - 14,273' Approx, 9,321 - 9420' 2-7/8" L-80 12,972' Packers and SSSV Type: Packers and SSSV MD (ft): Baker S-3 Packer Baker S-3 Packer 12,972' 12, Attachments: Description Summary of Proposal U 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15, Well Status after proposed work: Commencing Operations: 7/18/2005 Oil 0 Gas D Plugged 0 Abandoned D 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ D WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ~/ x. .r"~~ Title Ip¿1j¡'G-t'ØL.. ~1""- Signature 4~ Phone !¿'f-7J~r;:r Date 71I.Ç/P~ COMMISSION USE ONLY I · Same MD TVD 120' 120' 1,987' 1,967' 6,536' 5,064' 12,946' 9,420' 14273' 9,561' Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ...90 S- ......... ( '7 Y Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 O1I1er ~O()\>o;\ ~(J'ì( ~";,~ <ü..'\. ~ \C>..,,~D ~\0? rc.~ ""-<I:. " \-- \'~, de> ~tM.. ()- S , ~'6<0 Subsequent 0. () ~ ~~~ APPROVED BY _ / /fA. COMMISSIONER THE COMMISSION KtiUMS HI-L JUl 1 9 2005 Date: ~g / of Form 10403 Revised 11/2004 / Submit in Duplicate ORIGINAL 07/15/2005 18:53 FAX 907 258 8601 FOREST OIL ALASKA [41001 ) ) ~ FOREST OIL C:ORPORATION /Y/'~ Cß (Y' /J-/O Q/)/ Q/(;IC(-!Æ'1/ . o'/Ut.'tf?- 700 QQt;1.cho/)ca.//-t-?/ Ct:;f'lalka .9,9/i(}1 (907) ,2,5'S-SôOO · (9177) ,~,5'S-S6'OI (çff0,~) July 15, 2005 Mr. John NOlman, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: WMRU 7 A Coiled Tubing Cleanout and Perforation Acid Wash Dear Mr. Norman, The WMRU 7 A went off line after a jet pump change. Attempts to pump fluid down the well proved unsuccessful. Attached is a Sundry Notice to perform a clean out of this well utilizing coiled tubing. This clean out will be followed by an acid wash of the perforations. Attached please find a completed Form 10-403 for the work, a current wellbore schematic, a work over procedure, and a BOP configuration sketch for the coiled tubing unit to be used. If you have any questions, please contact me at 868-2137. Sincerely, ~~~~ Ted E. Kramer Production Manager Forest Oil Corporation Attachments: 10-403 Application for Sundry Approvals Work Over Procedure Wellbore Schematic - WMRU #7A CTU BOP Schematic OR\GINAL 07/15/2005 18:54 FAX 907 258 8601 FOREST OIL ALASKA [41003 ) ) FOREST OIL CORPORATION W. McArthur River Unit #7A Coiled Tubing Cleanout & Acid Wash Program (Preliminary) 6/24/05 . Transport tractor & driver to move in tanks and coiled tubing equipment . Vacuum truck to clean out flowback tanks and to flush out one c1e~ fluid tank. after the fill cleanout portion of job, and to clean out all tanks after the acid wash flowback is completed. Procedure: 1. Rig up flowback piping and tankage to well, consisting of two 500 bbl tanks for clean fluid storage, two 500 bbl tanks for flowback cleanout fluids, choke manifold from the well, and tank manifolding to flowback tanks to allow switching from one tank to another during the job. 2. Load clean fluid tanks with 750 bbls fresh water 3. Mix cleanout fluids to 20/0 KCL w/friction reducer by circu1ating through tanks until a unifonn mixture is achieved 4. Rig up coiled tubing unit, pump unit, Nitrogen Unit, Nitrogen tanks, manifolding, mixing & filtering equipment. Pressure test pumping and nitrogen lines to 4500 psi. 5. Rig up BOPE's and pressure test to 3000 psi. 6. Rig up Injector Head and pressure test to 3000 psi 7. Conduct pre-job Safety Meeting with all personnel on location to discuss job assignments and to clarify emergency procedures 8. RlH with coiled tubing, release sub, and jetting nozzle, at 70 fpm while circulating through coil at low rate, taking frequent pulling weight checks while RIH. Monitor flowback piping for any fluid returns. 9. At 11,000' MD, slow speed to 20 fpm and increase , pump. rate to 1.25 bpm to jet clean tubing through interval from 11000' to end tubing (Note: 1.870" ID X nipple at 12,808' MD) 10. Once top of liner at 12,811 ' MD is reached, stop RIH. Pump KCL slick water at 1.25 BPM rate and nitrogen at 350 cfm to provide slightly underbalanced well bore flow conditions. Continue to circulate until stabilized returns are achieved. Clean out fill in 4 Yí" slotted liner from 12,811' MD to 14,273' MD. Penetration rate should be about 10 fpm. 11. Monitor returns and estimate flow rate from tank strappings. Once solids are detected in flow stream, take samples of recovered fill material at several different times and visually inspect. Label several samples and save for laboratory analysis. 12. Once TD at 14,273' MD is reached, circulate offbottom for approximately 1 hour. Drop ball to change jetting nozzle to reverse direction mode 13. POOH with coiled tubing at about 25 fpm while continuing to pump KCL and Nitrogen for wiper trip across slotted liner 14. After the jetting nozzle enters the tubing at 12,800', MD, slowly increase POOH speed to 70 fpm while continuing to pump KCL and Nitrogen 6/27/20059:04 AM Created by Eric Skaalure Page 2 of 4 07/15/2005 18:55 FAX 907 258 8601 ') FOREST OIL ALASKA [41004 ) FOREST OIL CORPORATION W. McArthur River Unit #7A Coiled Tubing Cleanout & Acid Wash Program (Preliminary) 6/24/05 15. Mix a total of 16,100 gallons (383 bbls) of 10% HCL One-Shot Plus acid system in a clean Tiger Tanle Perform QAlQC tests on acid to verify acid, strength and acceptable sludge test performance. 16. Remove flowback fluids from tanks to provide sufficient volume of +/- 500 bbls for subsequent acid wash flowback fluids 17. Break open CT lubricator; remove jetting nozzle and Rig up Roto-Jet Tool on CT. 18. Conduct pre-job safety meeting for acid wash job. Confinn job assignments and review emergency procedures. 19. Pressure test CT lubricatorlBOP's 20. RIH with coiled tubing, release sub, and Roto-Jet nozzle, at 70 fpm while circulating through coil at low rate, taking frequent pulling weight checks while RIH. Monitor flowback piping for any fluid returns. 21. At 12,700' MD, slow speed to 20 fpm while passing through jet pump cavity, packer, and 1.870" ID X nipple at 12,808' MD (end of tubing at 12,814'MD) 22. Once below tubing tail, increase ROP to 70 fpm and run to TD at 14,273'MD. 23. POOH while spotting 2200 gallons of acid/xylene across slotted liner interval. Park CT above ~cid and allow acid to soak for 30 minutes. 24. RIH to TD at 14,273'MD. POOH at 10 fpm while pumping acid through Roto-Jet tool at 1.25 BPM. Wash to top of slotted liner at 12,946'MD. (Note: ROP & Pump rate through Roto-Jet tool to be confirmed with CIRCA simulation). 25. RlH to TD at 10 fpm while conducting second pass of acid wash through Roto-Jet tool. 26. Start pumping N2 at 500 scfm and POOH at 50 fpm while unloading well to tanks. Ensure acid volume is unloaded prior to pulling CT nozzle into tubing tail. 27. Continue POOH at 70 fpm 28. Rig down Injector Head & BOPE's 29. Rig down CT Equipment 30. RU Slickline Unit. 1nstal1 Standing Valve. 31. Rig down temporary piping from well and reconnect flowline. 32. Pump down Jet Pump and put well on production 33. Obtain well test to verify well perfonnance 34. Clean out flowback tanks and clean up location 6/27/20059:04 AM Created by Eric Skaalure Page 3 of 4 07/15/2005 18:55 FAX 907 258 8601 ') FOREST OIL ALASKA [41 005 ) West McArthur River Unit #7A Completion 20" 129#, X-56 Driven Conductor 120' MD - 120' TVD 133/8" 68#, L-80 BTC Surface Casing 17 1/2" Hole 11981' MD - 1,961' TVD 9 5/8" 47#, L-80 BTC Intermediate Casing 12 1/4" Hole ~ 4 6,536' MD - 5,064' TVO' Trico JetPump - 12,724' MD 7 5/8" 29.7#, L-80 Hy 521 Intermediate Liner 8 1/2" Hole Baker Model 8-3 Packer - 12,792' MD' Liner Top -12,811' MD 12,946' MO - 9A20'TVD 4 1/2" 12,6#, L-80 18T Slotted Production Liner 6 3/4" Hole 14,273' MO - 9,561' TVD FOREST OIL ALASKA 07 258 8601 S 07/15/2005 18: 55 FAX 9 "'ìi6 5606 BJ SERVICE '07 FAX 90 1 07/15/2005 FRI 17. , ) [41 006 I4J 002/002 ~o7 ~,5eí -p 5k- 011(,11!f V è.! Úe Möp1~r fJv[1) J i C)O" I ~~rl I l . ~ J ~ .,I ... . ~~.~ " .... 1 , i'~X 1 \ l~ .,...,- ~--=-.... -.. /. tl, e...,., ~,u""". ~-~:'~:".' ._.;::':4:- J.{}f~ --}Ö IùÖ~ I :::..__ "_..: .... -~ --r- " B \ì "'" ~ Þ.." "^ <;, r~ ~ \..... e.,-,.,..... ~ .,Þ \ ~ ) Y1..11 ~\~ ~ Rc}.w\.s J l .. I X' T w. "" ~IA ~ R 0...... ') J - - '~ ì l r - JS"02 ,. L' F)ou..":) ~,('Os. s Sk~.c}.~~ . '1 ) I __ [ ·.ll ':1¡," - IDM F)(;.....~e - _ I '-'1YJI.,.' I - } OW! r: ) ¡). .... "~~ e I-..~ ,. ~1 4}{~' - 10M. F/,:,v"\" .' I n n n n n '-f :/J(...' . - ! 0 ¡A · j- I" v· '....," I - 1 D51\ '),... lJ '-U' \J-U ö1í",,"-. ¡OM r Chl"'~.},: U .' I ~')I~' _ IbM r-IOVl~1!. r I\~?-} \/ Y 'I y¡';' ~ ) o't'v\ nCA."'~e I . , 1 3~/p'{ - J 0 t\Á.. F) A '^~ e 1 . ~- - J ~j1~' - ~ M )-~CÀ,^-~e. .. DATA TRANSMITTAL To: Phone: L.) <'J Forest Oil Corporation Alaska Division 310 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 RECEIVED JUL 0 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Date: July 6, 2001 Lisa Weepie/Howard Oakland AOGCC 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 From: Barbara Murray Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Phone: (907) 258 - 8600 FAX: (907) 258 - 8601 TRANSMITTAL DESCRIPTION ... ~.Well ,¡ vWMRU-7 .J."~MRU-7st p' vWMRU-7 v'WMRU-7st vWMRU-7 ¡,WMRU-7st /WMRU-7st / l/RU -2 X/RU -2 ~,D~ /RU -2 ~O . RU -2 -gU-2 'RU -2 "RU -2 ,RU -2 '. RU-2 'RU -2 ". RU-2 . RU-2 ;RU-2 ;RU-2 RU-2 /RU -2 RU -2 " RU-2 API Number 50-133-20500-00 50-133-20500-01 50-133-20500-00 50-133-20500-01 50-133-20500-00 50-133-20500-01 50-133-20500-01 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 Description ~ . . .7r' Data From: 1-Final Well Rep~RANNED NOV Ij"2004 Epoch 1-Final Well Repo'rt ,/ Epoch 1- velum 2"=100' MD Mudlog Epoch 1-velum 2"=100' MD Mudlog Epoch 1- CD Final Well Data Epoch 1- CD Final Well Data Epoch 2 boxes - Dryed cuttings for WMRU-7st Epoch 2 boxes - Dryed cuttings for RU #2 Epoch 1- Final Well Report Epoch 1-velum 2"=100' MD Mudlog Epoch 1- CD Final Well Data Epoch 1 film -Gamma Ray, Neutron-run 4(236'-3685') Schlumberger 1 film-Repeat Formation Tester-run 4(14424'-15164') Schlumberger 1 film -Dipole Shear Sonic-run 4(14356'-15338') Schlumberger 1 film-Array Induction, 0, N, GR - PE - run 4(14356'-15338') 1 film-Array Induction Dipole Shear Sonic -run 4 (14356'-15338') 1 film-Caliper Log -run 4 (14356'-15338') 1 film-Combinable Magnetic Resonance Tool-run 4 (14400'-15200') 1 film-Ultrasonic Borehole Imager -run 5(14360-15050) 1 film-Ultrasonic Imaging Tool-run 5 (14126-15234) 1 film-Cased Hole Formation Resistivity Gamma Ray- run 5(13800-14600) 1 film-Cement Bond Tool -run 5(14126-15234) 1 film-Temperature Log Baseline and Post Injection (100-9000) 1 film-Array Induction, 0, N, GR, Caliper - PE - run 3 (12900-14695) 1 film-Array Induction, Sonic DT Compressional, GR (12900-14695) RU2 and WMRU-7st to AOGCC.xls/Page1 Date Modified:7/6/01 Date Prepared: 12/6/00 bk R~L --.. YU-2 .Æ:U -2 vRÚ -2 v-RÚ -2 /' vRU -2 "RU -2 ¡/RÜ -2 v~U -2 vRU -2 A~lJ -2 \/~tt.-2 kRU -2 ,/RU -2 ,,/.RU -2 ,//RU -2 ~~U -2 'iiu -2 . /' /RU -2 LRU -2 v/RU -2 'v'R L),. - 2 tì.~U -2 /'HU - 2 ~/'RU- 2 -RU -2 ,/RU -2 '--RU -2 i/RU -2 v,RU -2 /RU-2 .~-/RU- 2 j"RU -2 Y"RU -2 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 50-733-20501-00 J . .-.) () 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-Array Induction, Density, Neutron, GR (8800'-13209') 1 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') 1 paper - Gamma Ray, Neutron (236'-3685') -5/18/01 1 paper - Array Induction, Sonic DT Compressional, GR (12900-14695) 1 paper- Cement Bond Tool (14126-15234) -5/28/01 1 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') 1 paper - Caliper, Gamma Ray (3213'-8976') 3/15/01 1 paper- Ultrasonic Borehole Imager (14360'-15050') 5/18/01 1 paper - Ultrasonic Imaging Tool (14126'-15234') 5/28/01 1 paper - Ultrasonic Borehole Imager, Gamma Ray (9019'-13209') 1 paper - Dipole Shear Sonic (14356'-15338') 5/18/01 1 paper - Dipole Shear Sonic Log, Gamma Ray (9019i_13209') 4/9/01 1 paper - Dipole Sonic Imaging (12900'-14695') 4/26/01 1 paper - Dipole Shear Sonic I.mage (3212'-8976') 3/15/01 1 paper - Array Induction, Dipole Shear Sonic (14356'-15338') 5/18/01 1 paper - Array Induction, Dipole Shear Sonic (3212'-8976') 3/15/01 1 paper-Array Induction, Density, Neutron, GR, Cal- PE (3212'-8976')-3/15/01 1 paper-Array Induction, D, N, Gr, Cal-Platform Express (8800'-13209')-4/9/01 1 paper-Array Induction, D,N,Gr,Cal-Platform Express(12900'-14695')-4/26/01 1 paper-Array Induction, D,N,Gr,Cal-Platform Express(14356'-15338')5/18/01 1 paper - Caliper Log (14356'-15338') - 5/18/01 1 CD - UBI Break out Data (8998'-15036') - 5/7/01 1 CD - AIT/PEX.lDSI data (12770'-14717') - 4/26/01 PDS format 1 CD - Open Hole Logs - to 9000' 1 notebook - DST and RFT testing Data Please sign below to acknowledge receipt. ~Ja j..:1 L !~VL~"V,-~ Received BY~ q tJ Date: Co ~ ~ { ^~ ~ \ Returned to Forest Oil Accepted By: Date RECEIVED SCA,NNEC NO\1 1 5 20D4 JUL 0 6 2001 RU2 and WMRU-7st to AOGCC.xls/Page1 A\aska Oil & Gas Cons. Commission ^nchorage Date Modified:7/6/01 Date Prepared: 12/6/00 bk Permit to Drill 2010420 MD 14273 TVD DATA SUBMITTAL COMPLIANCE REPORT 4~8~2003 Well Name/No. W MCARTHUR RIV UNIT 7A Operator FOREST OIL CORP 9561 Completion Dat 4/27/2001 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-133-20500-01-00 UIC N _ . REQUIRED INFORMATION Mud Log No Sample Nc) Directional Survey ~ _k_/~/_~,_ _ . DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Interval Log Log Run Name Scale Media No Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments L L C C R R ~Madlog 2 FINAL 6748 14273 ~,...40177 FINAL 9650 14269 9650 14269 E~-~/e II Report FINAL CH 7/6/2001 6748-14273 Mudlog CH 7/6/2001 10177 9650-14269, Digital Data Case 7/6/2001 10177 9650-14269 CH 7/6/2001 End of Well Report Well Cores/Samples Information: N~me ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Interval Dataset Start Stop Sent Received Number Comments Daily History Received? Y / N Formation Tops ~ N Analysis Y / N R~.r~.ivP. d ? Comments: '~'~- ,.E'~ ![0 ua ~ ~ Compliance Reviewed By: FOR EST OIL C O R P O R A T ! O N May 30, 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) West McArthur River Unit #7A Enclosed is Forest Oil's Well Completion Report and Log for the West McArthur River Unit #7A. This well was drilled as a development well into the West McArthur River structure. Production is from the Hemlock formation. WMRU #7A was drilled from the original WMRU #7 wellbore, through an openhole sidetrack at 9,834' MD. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager- Alaska Division Forest Oil Corporation Attachments: Well Completion Report (form 10-407) West McArthur River Unit #7A Well Schematic Daily Operations Summary Final Directional Survey ORIGINAL ( STATE OF ALASKA N(t,O' ALASKA OiL AND GAS CONSERVATIO MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG "1. Status of Well Classification of Service Well .~'O~IL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Namb of Operator 7. Permit Number Forest Oil Corporation 20~-042 =3. Address 310 K Street, Suite 700 8. APl Number Anchorage, Alaska 99501 50-133-20500-01 '~. Local~on of well at surface ~"/"/~ '""~~ :'" . ', ' ~.o.~,..~.~.~;.-,~ ~....;i 9. Unit or Lease Name 2395' FNL, 1337' FWL, Sec. 16, T08N, R14W, SM West McArthur River Unit AtAt Top Producing IntervalTotal Depth '' ~ "~':~'"~':~ '~?~-~-~?~'~/'-~',: ,~;r,~,. '~----,--.---~ - : ! ¥ ii 10. Well NUmber 11. Field and s c. sM No., 1762' FNL, 2561' FWL, Sec. 10, T08 ,N, R14W, SM :';~ · ~'~" West McArthUr River' Field , '5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Sedal 16,3 KBI ADL 359111 "..,' ~:' .;'.! t.~! -12. Date Spudded 13. DateT.D. Reached 114. DateComp.,Susp. orAband. 115. Water Depth, if offshore 16. No. ofCompletions 1/1/01 4/5/01 4/27/01 n/a "!;:'~MSE~¢~':~ ~ :? : ~''' .?i.~.:.!':!;. ~"~F~;~.i,~Si.:,t, · , "17. Total Depth (MD+TVD)18. Plug Back Depth (MD+-rVD)I 19. Directional Survey I 20. Depth where SSSV set Thmkness of Permafrost 14,273' MD 9,561' TVD n/a Yes: x No: , n/a ,feet MD , n/a 22. Type Electric or Other Logs Run 8. 1/2" Hole - Quad Combo, UBI 6 3/4" Hole - LWD (Gamma and Res) ..... "23. CASING, LINER AND CEMENTING RECORD ' SETTING DEPTH MD ' " CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , , , , 20" 133# K-55 Surf. 120' driven n/a None , , ,, , , ,,,, ,.,,, , ...,,.,,.,. 13 3/8" , 684f L-80 Surf. , , 1~831' , 17 1/2" 2682 cu ft , None 9 5/8~ 47# L-80 Surf. 6~986' 12 1/4" 448 cuft , None 7 5/8" 29.7# L-80 6~321' 12~946' , , 8 1/2" , 194 cuft None 4 1/2" 12.6 # L-80 12~811' 14,273' 6 3/4" n/a None , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ,, SIZE ' DEPTH SET (MD) ' 1SACKER sET (M~)),' .... 2 7/8" 12~814' 12~792', ........... 26. ACIDi FRACTURE, CEMENT SQUEEZE, ETC. DEPTH,INTERVAL (MD) AMOUNT & KIND OF MATERIAL US,ED n/a n/a , , , , , , , ,,, , , ,, ,,. , , , 27. "' PRODUCTION TEST' Date First Production" I Method of Operation (Flowing, gas lift, etc.) ........................... 2,5-Apr-01I Downhole Jetpump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF wATER-BBL CHOKE sIzE I GAS-01L RATIO 25-Apr-01 13 TEST PERIOD => 1282 301 154 n,/a ,I 235 ., Flow Tubing Casing 'Pressure CALCULATED OIL-B'BL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 4000 35 psi 24-HOUR RATE => 2367 556 284 27.7 28. CORE DATA , , . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No coring was done. Hemlock formation consisting of interbedded sands and conglomerates. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 't 30. '~,. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH SSTVD GOR, and time of each phase. Hemlock Bench 1 12,964' 9,269' Hemlock Bench 2 13,028' 9,315' Hemlock Bench 3 13,150' 9,365' ":'" .~; !",i .., 31. LIST OF A~ACHMENTS Well Schematic, Final Directional Su~ey 32. I hereby ~~~ is true and correct to the best of my knowledge ~--/~0/ Signed , _ _ Title__Drilling Manager Date , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 West McArthur River Unit #7A Completion 20" 129~, X-56 ~ 13 3/8 68#, k-80 BTC ~ ,S~ llrfa2c,,eHCola;i ng I~ 9 5/8" 47#, L-80 BTC Intermediate Casing 12 1/4" Hole 7 5/8" 29.7#, L-80 Hy 521 Intermediate Liner 8 1/2" Hole 4 1/2" 12.6#, L-80 IBT Slotted Production Liner 6 3/4" Hole 120' MD - 120' TVD ,987' MD - 1,967' TVD 6,536' MD - 5,064' TVD Trico JetPump- 12,724' MD Baker Model S-3 Packer- 12,792' MD Liner Top- 12,811' MD 12,946' MD - 9,420' TVD 14,273' MD - 9,561' TVD FOREST OIL CORP. Page 1 of 21 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date [ Fr°m -T° 1 H°urs ~ C°de '~ Sub I Phasei~ ,Code Description of Operations 12/15/2000 00:00 - 00:30 0.50 01 lB I RDMO i Slip extra drilling hne to rig down Tesco topdrive. 00:30 - 06:00 5.50! 01 ' B RDMO ~ Rig down Tesco topdrive. 12/16/2000 106:00 - 09:00 3.00 01 B I RDMO Finish laying down top drive, hydraulic hoses,track etc. 109:00 - 12:00 3.00 01 B RDMO Clean pits, take down crown saver, rig up crane with Toloff, lay down 2" cement line, lay down derrick camera. 12:00 - 18:00 6.00 01 B RDMO Continue hauling off excess fluids from pits, clear rig floor, excess subs, handling tools, tongs. Unstring wire-line and Geolograph line from derrick. PJSM Bridle up. Remove top stabbing board brace from derrick, remove driller's roof. 18:00 - 00:00 6.00 01 B RDMO Finished hauling excess fluids from pits. Clean pits for rig moves. Remove stand pipe bottom section and cement hose from derrick. Remove gas buster lines from gas buster. 00:00 - 06:00 6.00 01 B RDMO Rig down choke lines, gas busterlines, flowline hydraulic ram, work in pits, build loads for trucks. Remove trip tank lines. 12/17/2000 06:00 - 12:00 6.00 01 B RDMO Finish laying down gas buster and hydraulic rams. Build loads for trucks. Lay down windwalls, beaver slide and gas buster with crane. 12:00 - 17:30 5.50 01 B RDMO PJSM Fold back wind-wall, remove stairs from rig to pits. Tie back all cables and lines in derrick. Clean pits and prepare pits for rig move. Remove lower cellar V-door wind-wall, front floor plates and beams. Unstring small tugger, secure derrick climber to derrick. 17:30 - 00:00 6.50 01 B RDMO Move boom poles into position and secure board. PJSM with rig crew, lower derrick onto derrick stand. Installed drilling line support chains in derrick. PJSM Hang blocks and secure to derrick, secure boom poles to derrick. Prepare shaker exstension section to be moved from pits. 00:00 - 06:00 6.00 RDMO Lay down board from derrick. Unspool drilling line. Continue rigging down. 12/18/2000 06:00 - 12:00 6.00 01 B RDMO Rig down, hang blocks, unchain draw-works, blow draw-works down. Prepare to take draw-works off subs. Blow down steam lines to sub and floor. Lay A-legs over. 12:00 - 00:00 12.00 01 B RDMO PJSM Unpin derrick and move from rig floor. Secure bridle lines to top of derrick with crane. Lower off drillers side dog house, choke manifold,. steam heater, big tugger from rig floor. Move shaker exstension section from pits. Break apart air lines, water lines, in upper sub base sections. 00:00 - 06:00 6.00 01 B RDMO Remove cellar dolly. Perpare parts house to move. Remove mud dock. Prepare loads to transport to WMRU #7. Finish preparing draw-works for moving. 12/19/2000 06:00 - 12:00 6.00 01 B RDMO Moving rig. Tear down, load trilers, take down stairs elevator from drillers dog house and remove dog house. Clean mud pits. Continue loading out trailers. 12:00 - 00:00 12.00 01 B PJSM Move traction motor shed, pipe rack, draw-works, rotary table, floor plates, center beams from rig floor and sub. Clean pits with Unocal super sucker. 00:00 - 03:00 3.00 01 B Continue cleaning mud pits. 03:00 - 06:00 3.00 01 B Rig down pits. 12/20/2000 06:00 - 12:00 6.00 01 B RDMO Blow down water and steam lines. Rig down substructure with crane. Unstack all three sub bases. 12:00 - 00:00 12.00 01 I B RDMO PJSM Prepare pits to be moved, fold top sub braces, remove bottom sub braces and secure for rig move. 00:00 - 06:00 6.00 01 B RDMO Shut down operations for the night. 12/21/2000 06:00 - 09:00 3.00 01 B MIRU Set fuel tank, work on draw-works, cover cellar, grade location, load and unload trilers. Recieve draw-works, unload from truck. 09:00 - 13:30 4.50 01 A MIRU PJSM Reposition derrick with crane for truck and load. Move derrick from location, move sub base mats. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Operations Summary Report Page 2 of 21 Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date !From-To Hours Code 'cSoUdbe Phase ....................................................... De~cr!p!,ior~..~.!,ope.!.~!i.cm.s~ 12/21/2000 '13:30- 19:00 ' 5.50i 01 A 12/22/2000 12/23/2000 12/24/2000 12/25/2000 19:00 - 06:00 06:00 - 07:00 07:00 - 19:00 19:00 - 06:00 06:00 - 07:00 07:00 - 19:00 19:00 - 06:00 06:00 - 07:00 07:00 - 19:00 19:00 - 06:00 06:00 - 07:00 07:00 - 19:00 19:00 - 06:00 06:00 - 07:00 07:00- 19:00 19:00 - 06:00 06:00 - 21:00 12/26/2000 12/27/2000 01 A 01 01 01 01 01 01 1.00 01 5.00 01 MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU MIRU iMIRU Cleaned up cellar and sub area, removed herculite. Moved slop tank away from pits, mud dock braces and pit stairways, moved electrical shop, loaded man-lift. Moved boiler blow down tank. Blew down fuel lines from motor complex to fuel tank with air. Shut down for the night. Crews did not start until 07:00 hrs. Lay herculite, mats, unload trilers, replace valves on water tank, build fuel berm. Set oil line for production. PJSM Load out loads from Tomcat #1 to WMRU #7. Remove breeze way from pump room to motor complex and load. Split and load motor complex, load scr room, shaker and volume pits. Load #1 boiler shed and pick up motor complex mats. Shut down for the night. Crew started work @ 0700 hrs. Set lower sub-bases, level and align over WMRU #7, set upper sub- boxes and pin same, put spreaders in lower and middle subs, offload trailers, offload barge, prepare trailers for back load on barge, offload fuel in storage tanks, work on sheave bracket for counter weight at crown. PJSM Load up excess fuel from Kustatan #1 from #1 fuel tank, load out #2 boiler shed, rig pumps. Load out two sections of pump room. Shut down for the night. Crews did not start until 0700 hrs. Finish installing pipe rack spreader, install rotary, rotary floor plate,gatortail piperacks, draw-works, and draw-works traction motor house. Shut in wells #1 and #6 for two and a half hours, while setting spreaders etc. on sub-base. PJSM Move last pump room section, pick up remaining rig mats and herculite, clean location and load out loads forom Kustatan #1 to WMRU #7. Shut down operations for the night. Operations shut down for the night. Set floor plates, set drillers side and off drillers side dog houses. Set choke manifold, hook up choke line through floor. Hook up draw-works traction motor chain and install gaurd on same. Plumb service lines to draw-works. Run choke control lines. Load derrick on truck and position in front of sub. Pin derrick to sub. Pin bridle lines, set drlg. line on rig floor. Remove chain holding drlg. line in derrick. Start dressing derrick to raise. Load out loads from Tomcat #1 and clean location. Lay down felt pad and herculite for pump room. Heat weld herculite together. Set mats and pump room. Shut down operations for the night. Merry Christmas! Operations shut down for the night. Pin a-legs, pin derrick board, set stairs and elevator to rig floor. Install landing braces for mud dock and set mud dock. Hook up service lines, install electric cable tray to sub. Help pull elctric cables. PJSM Set rig pumps in pump room and breeze way. Spread herculite for motor and boiler complex. Heat weld herculite. Lay down felt pad and spread herculite and mats for pits. Set pits. Weld on derrick stand all day. Shut down operations for the night. M/U LINES IN SUB, PITS, PUMP ROOM & BREEZE WAY, SET LANDINGS & STAIRWAYS F/PITS, SET MAT F/TESCO UNIT. R/U HYDRAULIC, STEAM & WATER LINES F/PUMP ROOM T/SUB, SET BOILER BLOW/DN TANK, SPREAD OUT HERCULITE F1 #1 & #2 FUEL TANKS. SET SCR BLD, SUITECASES W/SERVICE LINES F/ Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Operations Summary Report Page 3 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Fr°m- T° ..H.°_.U~.S. ......... ~de 12/27/2000 !.06:00-21:00 15.00 01 12/28/2000 12/29/2000 12/30/2000 12/31/2000 1/1/2001 21:00 - 06:00 06:00 - 15:00 15:00 - 22:00 22:00 - 06:00 06:00 - 20:00 20:00 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 09:00 09:00- 12:00 12:00 - 00:00 00:00 06:00 12:00 22:00 00:00 03:00 06:00 07:00 09:00 10:00 11:30 12:00 12:30 13:00 15:30 16:30 20:00 - 06:00 - 12:00 - 22:00 - 00:00 - 03:00 - 06:00 - 07:00 - 09:00 - 10:00 - 11:30 - 12:00 - 12:30 - 13:00 - 15:30 - 16:30 - 20:00 - 20:30 West McArthur River Unit #7 West McArthur River Unit #7 Spud Date: 12/29/2000 ORIG DRILLING Start: 12/13/2000 End: NABORS ALASKA DRLG Rig Release: Group: NABORS DRILLING Rig Number: 160 ..Su.b Phase Description of Operations MIRU MIRU MIRU MIRU MIRU MIRU CSGDRV CSGDRV CSGDRV CSGDRV CSGDRV CSGDRV MIRU MIRU MIRU MIRU MIRU MIRU MIRU DRLSUR DRLSUR DRLSUR DRLCON DRLCON DRLCON DRLCON DRLCON DRLSUR DRLSUR DRLSUR DRLSUR DRLSUR DRLSUR 9.00 9.00 MTR ROOM. SET MTR ROOMS & BOILERS. SPOOL DRLG. LINE ON DRAWWORKS, UNCHAIN BLOCKS, PREPARE TO RAISE DERRICK. SET # I FUEL TANK, P/U TOOLS & BOARDS AROUND LOCATION. REPAIR PLUMBING ON # 1 FUEL TANK. SHUT DOWN OPERATIONS FOR NIGHT. CIO AIR LINE T/SUB, WELD DN PIPE STANDS BETWEEN SUB & PUMP ROOM. HOOK UP LINES BETWEEN PITS, PUMP ROOM & SUB. CHECK DERRICK, FILL WATER TANKS & CIRC. SET MATS & SLOP TANK, INSTALLED SHAKER EXT. BLD. HOLD PJSM, RAISE DERRICK, HOOK UP TUGGERS. SET FRONT WINDWALLS ON RIG FLOOR. SET GAS BUSTER, RAISE BACK & SIDE WINDWALLS. SET # 2 FUEL TANK IN BERM, SET PARTS HOUSE. START BERMING AROUND RIG. CONT. HOOKING UP LINES IN PUMP ROOM & PITS. INSTALL STAIRS ON O/DS. SET CAT WALK, P/U BEAVER SLIDE. : PJU FLOOR. R/U TARP BETWEEN SUB & PUMP HOUSE. INSTALL GASBUSTER U-TUBE, MAKE UP STANDPIPE, SET EPOCH, SPERRY, & M.I. BUILDINGS IN PLACE. INSTALL DERRICK LADDER, INSTALL CHAIN GUARDS ON DRAWORKS. HANG BRIDAL LINES IN DERRICK & TIE/BK. P/U POWER PACK & HAMMER FOR 20" CONDUCTOR, HOLD PJSM. WELD GUIDE TEMPLATE TO ROTARY TABLE, WELD DRIVE SHOE. CUT, DRESS & WELD 2 JTS. 20" DRIVE 42 ' OF CONDUCTOR PIPE. CUT, DRESS, WELD 3RD JT. 20". FINISH DRIVING 20" TO 118' KB (REFUSAL) LAY DOWN HAMMER & UNIT. CUT OFF CONDUCTOR PIPE & WELD FLOW LINE. START RIG UP ON TESCO TOPDRIVE, P/U SWIVAL HOLD PJSM. RIG UP TESCO, TORQUE TUBE, POWER PACK, GUIDE. P/U TOPDRIVE & PIN TO GUIDE, CIO MUD PUMP LINERS TO 6 1/2". INSTALL T.D. SERV. LOOP. MIXING SPUD MUD. RIG UP TESCO, C/O LINERS ON MUD PUMPS, MIXING SPUD MUD. R/U TESCO TOPDRIVE, FINISH CIO MUD PUMP LINERS TO 6 1/2. FINISH MIXING SPUD MUD. FINISH R/U TESCO. P/U BHA HWDP & STAND BACK IN DERRICK. HOLD PJSM & RABBIT. BHA, P/U & M/U BHA. ORIENT MOTOR. ATTEMPT TO CIRC. & TEST SURFACE EQUIP.( BURNT 20 COND. PLUG ON # 2 M.P.) TEST SURFACE MUD LINES TO 3,000 PSI, & #1 MUD PUMP. DRILL SURFACE TO 100 FT., P/U STAB. WORK ON TESCO TOP DRIVE. SURVEY. DRLG./SLD. SLD./DRLG. F/143 FT. T/230 FT. SURVEY. SLD./DRLG. F/230 FT. T/319 FT. POOH & L/DN BIT & X-O. P/UP HWDP & 5"'DP. WORK SLACK IN TARP ON TESCO SERVICE LOOP & RETIE. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 4 of 21 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 'Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date I From- To Hours Code ~S..u,b.~ I Phase Description of Operations ....................................... i .............................................. 1 ............................ ......................... ............................. I I I 1/1/2001 20:30 - 21:00 0.50 26 I !DRLSUR I P/UP 5" DP. 21:00 00:00 3.00 26 ~ DRLSUR I~M/U NEW BIT P/U BHA, MK UP MWD PROBE. 00:00 - 01:00 1.00 26 DRLSUR M/U BHA. 01:00 - 01:30 0.50 06 J DRLSUR . RIH 01:30 - 02:00 0.50 25 DRLSUR :ATTEMPT TO BREAK CIRC. 02:00 - 03:00 1.00 06 A DRLSUR POH, LOOKING FOR RESTRICT. 03:00 - 03:30 0.50 06 A DRLSUR ATTEMPT TO BREAK CIRC. @ MWD. 03:30 - 04:00 0.50 06 A DRLSUR POH, BIT JETS PLUGGED. 04:00 - 05:00 1.00 06 J DRLSUR RIH. 05:00 - 06:00 1.00 02 A DRLSUR DRLG. F/319 FT. T/329 FT. 1/2/2001 06:00 - 12:00 6.00 02 A DRLSUR DRLG. F/329 T/597.SURVEY EVERY STD. 12:00 - 13:30 1.50 02 A DRLSUR RT. DRLG. FI 597 T/684. CIRC. 10 MIN, SURV. & GYRO. 13:30 - 16:00 2.50 02 A DRLSUR SLD. F/684 T/724, RT DRLG F/724 T/775. CIRC. SURV & GYRO. SLD. F/775 T/804. RT. DRLG F/804 T/863. 16:00 - 16:30 0.50 02 A DRLSUR SURV. & GYRO. CIO TESCO CYL. ON ELEV. 16:30 - 00:00 7.50 02 A DRLSUR SLD. & RT. F/863 T/1345 & SURV. 00:00 - 06:00 6.00 02 A DRLSUR SLD. & RT. F/863 T/1650. 1/3/2001 06:00- 13:30 7.50 02 A DRLSUR Drilling 17 1/2" surface hole. 13:30 - 14:00 0.50 07 DRLSUR Service top drive and rig. 14:00 - 15:00 1.00 29 DRLSUR Circulate and condition hole, monitor wel110 min. OK 15:00 - 17:00 2.00 06 H DRLSUR Pump dry job, POOH slow and SLM. 17:00 - 18:30 1.50 26 DRLSUR Work BHA, clean stabilizers and lay down UBHO HOC and probe and pony collar. 18:30 - 19:30 1.00 06 J DRLSUR Check bit. RIH. Make up stabilizer body and sleeve. 19:30- 20:00 0.50 07 DRLSUR Clean rig floor. 20:00 - 21:30 . 1.50 07 DRLSUR PJSM Cut and slip drlg. line. Inspect brake pads. Reset COM,OK. 21:30 - 23:00 1.50 06 J DRLSUR RIH w/HWDP. 23:00 - 01:30 2.50 26 DRLSUR Rabbit and pick up 5" DP. Run 3 stds. and stand back same. RIH. 01:30 - 02:00 0.50 02 DRLSUR Drill to 1987'. 02:00 - 03:00 1.00 05 DRLSUR Circulate hole clean. 03:00 - 06:00 3.00 05 F DRLSUR POOH lay down stabs, and MM. 1/4/2001 06:00 - 07:00 1.00 26 CSGCON Finish laying down, standing back BH^. 07:00 - 08:30 1.50 07 CSGCON Clean floor and clear tools. (BHA) 08:30 - 13:00 4.50 12 CSGCON Rig up to run 13 3/8" csg. Stabbing board, bales, LaFluer head, elevators and slips. PJSM. 13:00 - 13:30 0.50 07 CSGCON Readjust stabbing board winch. 13:30 - 22:30 9.00 12 CSGCON Pick up shoe, fill pipe and float equipment, verify floats are working. Run in hole slowly due to fluid loss. Circ every 10 jts. 22:30 - 00:00 1.50 29 CSGCON Tag fill 6' high. circulate bottoms up and wash down. Ran 49 jts. and landing jt. 00:00 - 01:00 1.00 12 CSGCON Space out 13 3/8" csg. Lay down landing joint. 01:00 - 02:00 1.00 07 CSGCON Rig down csg. equipment. 02:00 - 02:30 0.50 12 C CSGCON Prepare to cut off 13 3/8" csg. below rotary table. 02:30 - 03:00 0.50 12 CSGCON Cut off 13 3/8" csg. below rotary table. 03:00 - 04:00 1.00 12 CSGCON Rig up to run 5" DP inside 133/8" csg. to cement. 04:00 - 05:00 1.00 12 CSGCON RIH with 5" DP, tag float. 05:00 - 06:00 1.00 12 CSGCON Stab in float, rig up to circ. 1/5/2001 06:00 - 07:00 1.00 12 C DRLIN1 Rig up to cement, circulate. 07:00 - 07:30 0.50 12 C DRLIN1 PJSM 07:30 - 08:30 1.00 12 :C DRLIN1 Test lines to 2500 psi OK. 08:30 - 11:30 3.00 12 C DRLIN1 Pump 40 bbl. water- 362 bbl. lead cement @ 12.5 ppg. Pump 129 bbl. tail cement @ 15.7 ppg. Drop wiper plug and displace wih mud. Rig down. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 5 of 21 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date'i From -To Hours Code Sub ~ Phase Description of Operations 1/5/2001 [11:30 - 13:00 1.50.06 [G I DRLIN1 i POOH with 5' DP. Lay down pups jts., subs and valve. ~ ] , !13:00 - 20:30 7.50 14 i B DRLIN1 Rig down dresser sleeve, flowline. Cut 20' and 13 3/8" csg. stub. Make !and dress final cut. 20:30 - 22:00 1.50 14 B DRLIN1 Install 13 3/8" sliplock head. Test head to 1000 psi. 30 min test OK. 22:00 - 00:00 2.00 14 B DRLIN1 Rig up BOP trolley and BOPs. ~00:00 - 06:00 6.00 14 B DRLIN1 Nipple up BOP, pick up bag-double gates, mud cross-single gate-X/O spool. 1/6/2001 06:00 - 14:00 8.00 14 B DRLIN1 Finish nippling up. Install choke line, flow line, bell nipple, kill line, koomey hoses and turn buckles. Test 13 3/8" slip lock head to 1700 14:00 - 17:30 3.50 15 A DRLIN1 Test BOP, Koomey, choke manifold, 250 psi. Iow test, 3000 high. Test OK. 17:30 - 18:30 1.00 31 DRLIN1 Pressure test 13 3/8" csg. to 3000 psi. OK. 18:30 - 21:00 2.50 14 DRLIN1 Blow down choke manifold, install drip pans. 21:00 - 01:00 4.00 26 DRLIN1 Make up BHA. 01:00 - 02:00 1.00 06 A DRLIN1 RIH 02:00 - 03:00 1.00 02 D DRLIN1 Tag float collar @ 1946', drill out float and shoe @ 1987'. 03:00 - 04:00 1.00 02 A DRLIN1 Drill 25' of new hole to 2012'. 04:00 - 04:30 0.50 29 DRLIN1 Circ. bottoms up to test. 04:30 - 05:00 0.50 32 DRLIN1 F.I.T. test 12.5 ppg. mud wt. @ shoe. 341 psi. with 9.2 ppg. mud @ 1967' V.D. 05:00 - 06:00 1.00 02 A DRLIN1 Drilling 12 1/4" hole from 2012' to 2066'. Sliding mud motor for angle. 1/7/2001 06:00 - 00:00 18.00 02 A DRLIN1 Drilling and surveying 12 1/4" hole. 00:00 - 03:00 3.00 06 DRLIN1 Pump pressure increased. Unable to drill with slow pump rate and high pressure. POOH to find the cause for the pressure increase. 03:00 - 04:00 1.00 06 J DRLIN1 Work BHA. Cement dart was found on top of HOC. 04:00 - 06:00 2.00 06 J DRLIN1 RIH with BHA. Pick up 5" DP. 1/8/2001 06:00 - 08:00 2.00 06 A DRLIN1 Pick up 5" DP. 08:00 - 09:00 1.00 08 C DRLIN1 Fouled drilling line on draw-works and freed same. 09:00 - 10:30 1.50 06 DRLIN1 Pick up 5" DP. 10:30 - 11:00 0.50 29 DRLIN1 Circulate hole clean. 11:00 - 23:00 12.00 02 A DRLIN1 I Drilling 12 1/4" hole from 2912' to 3376'. 23:00 - 00:00 1.00 07 DRLIN1 Flow-line plugged while circulating hi-vis, hi-wt, sweep. Unplug flow-line. 00:00 - 06:00 6.00 02 A DRLIN1 Drill and survey 12 1/4" hole. 1/9/2001 06:00 - 10:00 4.00 02 A DRLIN1 Drilling 12 1/4" hole. 10:00 - 11:30 1.50 29 DRLIN1 Mix and pump sweep. Pump dry job. 11:30 - 13:30 2.00 06 A DRLIN1 POOH to shoe, monitor well, service rig. 13:30 - 14:00 0.50 07 DRLIN1 Lubricate rig. 14:00 - 16:00 2.00 06 A DRLIN1 POOH 16:00 - 17:30 1.50 06 A DRLIN1 Work BHA, lay down stab., lay down MWD probe, pick up new probe. 17:30 - 19:30 2.00 06 A DRLIN1 Make up BHA, RIH to DP. Tong die fell in hole. Keeper bolt in tongs broke. 19:30 - 21:00 1.50 06 A DRLIN1 POOH for mill tooth bit. 21:00 - 21:30 0.50 06 A DRLIN1 Clean rig floor from wet trip. 21:30 - 00:00 2.50 06 A DRLIN1 RIH with BHA. 00:00 - 01:30 1.50 06 A DRLIN1 Pick up 5" DP from catwalk. 01:30 - 02:30 1.00 07 DRLIN1 Cut and slip drilling line while circulating hole. 02:30 - 04:30 2.00 06 A DRLIN1 Pick up 32 joints 5" DP and RIH. 04:30 - 06:00 1.50 03 A DRLIN1 Ream 110' to bottom @ 3759' circulate out thick mud. 1/10/2001 06:00 - 12:00 6.00 02 A DRLIN1 DRLG. F/3759 T/4042. 12:00 - 00:00 12.00 02 A DRLIN1 DRLG. F/4042 T/4404. 00:00 - 06:00 6.00 02 A DRLIN1 DRLG. F/4404 T/4573. 1/11/2001 06:00 - 12:00 6.00 02 A DRLIN1 DRLG. F/4404 TI 4730. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 6 of 21 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From -To Hours Code (~(~b ~ Phase Description of Operations 1/11/2001 ! 12:00- 13:00 i 1.0002,IA DRLIN1 iDRLG. F/ 4730 T/ 4778. 13:00- 14:00 ! 1.00 05 iA [ DRLIN1 I SURVEY, CIRC. CLEAN HOLE TO SHORT TRIP. 14:00 - 17:30 3.50 06 H DRLIN1 POH, SHORTTRIP. 15 STDS. 17:30 - 00:00 6.50 02 A DRLIN1 DRLG. F/4778 T/4920. 00:00 - 06:00 6.00 02 A DRLIN1 DRLG. F/4920 T/5025. 1/12/2001 06:00 - 12:00 6.00 02 A DRLIN1 DRLG. F/5025 T/5115 12:00 - 00:00 12.00 02 DRLIN1 DRLG. F/5150 T/5360. 00:00 - 03:30 3.50: 02 A DRLIN1 DRLG. F/5360 T/5433.PUMPED HIGH VIS SWEEP. 03:30 - 04:30 1.00 10 E DRLIN1 SURVEY W/SPERRY, CBU, PUMP DRY JOB. 04:30 - 06:00 1.50 06 A DRLIN1 TOH F/NEW BIT. 1/13/2001 06:00 - 09:00 3.00 06 A DRLIN1 TOH F/BIT. '09:00 - 12:00 3.00 06 A DRLIN1 TOH W/BHA 12:00 - 13:00 1.00 06 A DRLIN1 LID MOTOR, BREAK STAB BLADES, STEERABLE BENT SUB & BIT. CLEAN RIG FLOOR. 13:00 - 16:30 3.50 15 A DRLIN1 TEST CHOKE, KILL LINE, HCR & BOP T/250 / 3000 PSI. TEST KOOMEY. 16:30 - 18:30 2.00 26 DRLIN1 P/U MAKE UP BHA, TEST SPERRY MWD TOOL. 18:30 - 19:30 1.00 06 A DRLIN1 RIH T/SHOE, CIRC. SERV. RIG. 19:30 - 20:30 1.00 29 DRLIN1 CIRC 40 STK MIN, 2030 STKS, BLOW DN TOP DRIVE. 20:30 - 23:30 3.00 06 A DRLIN1 RIH, WASH THRU TIGHT HOLE F/4603 T/4635. 23:30 - 00:00 0.50 03 A DRLIN1 REAM LAST 2 STDS F/5249 T/5433. 00:00 - 00:30 0.50 29 DRLIN1 CBU W/THICK GAS CUT MUD. MAX GAS 1192 UNITS. 00:30 - 06:00 5.50 02 A DRLIN1 DRLG. F/5433 T/5543. 1/14/2001 06:00 - 12:00 6.00 02 A DRLIN1 DRLG. F/5543 TI 5623. 12:00 - 00:00 12.00 02 A DRLIN1 DRLG. F/5623 TI 5775. 00:00 - 06:00 6.00 02 A DRLIN1 DRLG. F/5775 T/5878. 1/15/2001 06:00 - 12:00 6.00 02 A DRLIN1 DRLG. F/5878 T/5950. 12:00-00:00 12.00 02 A DRLIN1 DRLG. F/ 5950 T/ 6106. 00:00 - 06:00 6.00 02 A DRLIN1 DRLG. FI 6106 T/6220. 1/16/2001 06:00 - 10:30 4.50 02 A DRLIN1 DRLG. F/6220 TI 6281. 10:30 - 12:00 1.50 05 I DRLIN1 SURVEY W/SPERRY, PUMP HI VIS SWEEP CBU. 12:00- 12:30 0.50 05 I DRLIN1 CBU. 12:30 - 14:00 1.50 06 H DRLIN1 SURVEY, 9 STD. SHORT TRIP. 14:00 - 20:00 6.00 02 A DRLIN1 DRLG. F/6281 T/6334. 20:00 - 22:00 2.00 05 I DRLIN1 CIRC. SWEEP, MIX/PUMP PILL. 22:00 - 00:00 2.00 06 A DRLIN1 POOH. 00:00 - 03:00 3.00 06 A DRLIN1 POOH. 03:00 - 06:00 3.00 06 A ; DRLIN1 POOH, CIO BIT & STAB BLADES, PU STAB. 1/17/2001 06:00 - 07:30 1.50 06 A I DRLIN1 RIH w/BHA 07:30 - 08:00 0.50 06 A DRLIN1 RIH from 1140' to 1892'. 08:00 - 08:30 0.50 29 DRLIN1 Fill DP- Flow check w/Sperry Sun-Circ. hole volume. 08:30 - 09:00 0.50 07 DRLIN1 Service rig. Crown, blocks, and draw-works. 09:00 - 09:30 0.50 08 E DRLIN1 PJSM w/rig crew and top drive hand on CIO of grabber piston. 09:30 - 11:00 1.50 08 DRLIN1 CIO grabber piston on top drive. 11:00 - 11:30 0.50 08 DRLIN1 Reposition kelly hose. 11:30 - 15:00 3.50 06 A DRLIN1 RIH to 5903' 15:00 - 17:30 2.50 03 DRLIN1 Ream from 5903' to 6334', survey. 17:30 - 21:00 3.50 02 A DRLIN1 Drilling 12 1/4" hole from 6334' to 6351'. 21:00 - 21:30 0.50 05 DRLIN1 Circ. @ 6350' in attempt to clean bit. 21:30 - 06:00 8.50 02 A DRLIN1 Drilling 12 1/4" hole from 6351' to 6420'. 1/18/2001 06:00 - 20:30 14.50 02 A DRLIN1 Drilling 12 1/4" hole from 6420' to 6535'. 20:30 - 22:00 1.50 29 DRLIN1 Circulate bottoms up. Survey. S.P.R. 22:00 - 23:00 1.00 06 DRLIN1 8 stand short trip, hole OK. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 7 of 21 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date 'From-To Hours t Code /(~oUdb,, Phase Description of Operations I ' 1/18/2001 i 23:00 - 02:00 ~ 3.00 06 ] ! DRLIN1 Ciculate bottoms up. Pump dry job. Monitor well, OK. 02:00 - 06:00 ! 4.00 06 G DRLIN1 POOH to run 9 5/8" csg. 1/19/2001 06:00- 10:00 ! 4.00 06 G DRLIN1 Lay down BHA. 10:00 - 10:30 0.50 07 DRLIN1 Clear and clean rig floor. 10:30 - 12:00 1.50 12 A DRLIN1 Pick up test joint, pump out stack, pull wear-ring, set test plug. 12:00 - 14:00 2.00 12 A DRLIN1 PJSM Change bottom rams to 9 5~8". Dress threads on one door seal,one bolt and body. Test door seals to 3000 psi. OK. Pull test plug and lay down test joint. 14:00 - 17:30 3.50 12 A DRLIN1 Rig up stabbing board, remove elevators and bails. Make up LaFluer tool, put on long bails. Rig up csg. slips and elevators. 17:30 - 19:30 2.00 12 A DRLIN1 PJSM Baker lock first three joints. Fill csg. Check floats. OK. 19:30 - 20:30 1.00 12 A DRLIN1 Attempt to pull stabbing board away from top drive, did not work. Loosen top drive rail and move to drillers side. Center over hole. 20:30 - 01:00 4.50 12 A DRLIN1 Run 9 5/8" csg. to 2050'. 01:00 - 01:30 0.50 12 A DRLIN1 CBU 01:30 - 03:30 2.00 12 A DRLIN1 Run 9 5/8" csg. from 2050' to 3536'. 03:30 - 04:30 1.00 12 A DRLIN1 CBU 04:30 - 06:00 1.50 12 A DRLIN1 Running 9 5/8" csg. 1/20/2001 06:00 - 12:00 6.00 12 A CSGIN1 Run 9 5/8" csg. CBU @ 5085'. RUN csg. to 6535', make up landing joint, Circulate. 12:00 - 12:30 0.50 12 A CSGIN1 PJSM Lay down Lafluer tool. 12:30 - 13:00 0.50 12 C CSGIN1 Make up Cmt. head Circ. and work csg. 13:00 - 15:30 2.50 12 C CSGIN1 PJSM Test lines to 2500 psi OK. PUMP cmt per procedure. Chase w/ rig pumps. CIP 2 1520 hrs. 15:30 - 16:30 1.00 13 CSGIN1 Check float, holding OK. Blow down cmt. lines. Rig down cmt. head. 16:30 - 18:30 2.00 14 CSGIN1 Clean rig floor, drip pans, vac. oil from cellars. Use HOrsey to clean oil and make ready to nipple down BOPs. 18:30 - 23:00 4.501 14 B CSGIN1 PJSM Remove drip pans, Nipple down flowline. Nipple down BOP{s to set slips. :23:00 - 00:00 1.00' 14 B CSGIN1 Lift BOPs. Pull 150K on csg. Center csg. to set slips. 00:00 - 01:30 1.50 14 B CSGIN1 Set csg. slips. 01:30 - 02:30 1.00 14 B CSGIN1 Rough cut and lay down landing joint. 02:30 - 03:00 0.50! 14 B CSGIN1 DRop 3000#x50003 spool off stack. 03:00 - 04:00 1.00 14 B CSGIN1 Make final cut on 9 5/8" csg. 04:00 - 06:00 2.00. 14 B CSGIN1 Pick up tubing dpool and double studded adaptor. 1/21/2001 06:00 .- 07:00 1.00, 14 B DRLIN2 Make up well head flange, test BT seals to 1000 psi and hanger void to 2400 psi. OK 07:00 - 12:00 5.00 14 B DRLIN2 Nipple up stack, remove lifting cables from stack, change out pump liners from 6 1/2" to 5 1/2". 12:00 - 15:30 3.50 14 B DRLIN2 PJSM Nipple up flow line, install drip pans and turnbuckles. Gange bottom rams to 5". Continue cleaning pits. 15:30 - 17:30 2.001 07 DRLIN2 Lay down csg. elevators and slips, bails, tong hoses and stabbing board. Pick up regular bails and 5" elevators. Pick up tools and continue cleaning pits. 17:30 - 19:30 2.00 07 DRLIN2 Continue cleaning pits, run hose to pit for displacement of OBM. 19:30 - 23:30 4.00 15 A DRLIN2 Continue cleaning pits, test BOPs, choke manifold, floor valves and top drive IBOP, upper and Iower-250/4000psi. Test Hydrill 250/3000psi. OK. Pull test plug and set wear bushing. 23:30 - 00:00 0.50 07 DRLIN2 Cleaning cement out of sand trap. 00:00 - 01:00 1.00 07 DRLIN2 Clean pits. 01:00 - 02:00 1.00 31 DRLIN2 Test csg. to 3000 psi for 30 min. OK 02:00 - 06:00 4.00 06 K DRLIN2 Make up mule shoe, RIH with HWDP and pick up 5" DP. 1/22/2001 06:00 - 11:30 5.50 07 DRLIN2 Pick up 5" DP from catwalk. Rabbit each joint. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 8 of 21 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date I From - To Hours Code C~o~e I Phase Description of Operations 1/22/2001 11:30 - 00:00 12.50~ 07 , i DRLIN2 PJSM C ean cement out of sand trap with super sucker and shovels ' i and pick axes. Prep rig for OBM. ,00:00- 06:00 6.00 07 ;DRLIN2 I Clean cement from sand trap. 1/23/2001 06:00 - 10:00 4.00 05 K DRLIN2 Rig up to reverse out 11.4 ppg mud to fresh water. 10:00 - 10:30 I 0.50 05 K DRLIN2 PJSM with rig crew, tool pusher, co-man and mud man on reverse I circulation. 10:30 - 13:30 3.00 05 K DRLIN2 Reverse circulate @ 5921'. Displace 11.4 ppg. mud with fresh water. 13:30 - 14:00 0.50 05 K DRLIN2 Make conn., attempt to wash down. No go. 14:00 - 16:00 2.00 07 DRLIN2 PJSM Stand back two stands. Rig down hoses and blow down lines and top drive. Clean out degasser and desander pit under shakers. 16:00 - 19:00 3.00 06 A DRLIN2 POOH Lay down mule-shoe. 19:00 - 23:00 4.00 08 C DRLIN2 Hang blocks, realign hydromatic. Install gaurds. 23:00 - 02:30 3.50 07 DRLIN2 PJSM String new line through blocks. Cut off old drilling line. Spool old line off drum. 02:30 - 05:00 2.50. 06 A DRLIN2 Make up 8 1/2' drill out assembly. Flow check Sperry Sun MWD. 05:00 - 06:00 1.00 06 A DRLIN2 RIH 1/24/2001 06:00 - 10:00 4.00 06 F DRLIN3 TIH to 6010'. Fill DP @ 3615'. 10:00 - 11:30 1.50 02 D DRLIN3 Break circ.; drill cement f/6011' TO 6014'. 11:30 - 12:00 0.50 05 K DRLIN3 Rig up to displace w/oil base mud. 12:00 - 13:30 1.50 05 K DRLIN3 PJSM on displacing w/oil base mud. Check all equipment and get all people into position. 13:30 - 14:00 0.50 02 D DRLIN3 Displace hole w/OBM and drill cement f/6014' to 6022'. 14:00 - 16:30 2.50 05 K DRLIN3 Clean sand trap, degasser, and desilter pits. Plug water lines in pits. Change Popoff on #2 mud pump. 16:30 - 23:30 7.00 05 K DRLIN3 Take on OBM in pits to get volume to circulate. Go across shakers. 23:30 - 00:00 0.50 05 K DRLIN3 Start circulating slow to shear mud. 00:00 - 01:30 1.50 05 K DRLIN3 Circulate to build volume and transfer mud. 01:30 - 06:00 4.50 02 D DRLIN3 Drill out cement f/6022' to 6125'. 1/25/2001 06:00 - 07:00 1.00 02 . D DRLG. CEMENT F/6125 T/6129. 07:00- 11:30 4.50 06 ;A TOH F/ 6129 T/ 809. 11:30-12:00 0.50 06 A TOH W/BHA. 12:00 - 13:00 1.00 06 iA TOH W/BHA CHANGE BIT. 13:00 - 16:00 3.00 06 IA TIH, FILL PIPE @ 3200' 16:00 - 21:30 5.50 02 A BREAK CIRCULATION. DRILLING CEMENT F/6129' TO 6490' 21:30 ~ 22:00 0.50 29 CIRCULATE BOTTOMS UP 22:00 - 23:00 1.00 31 TEST CASING TO 3000 PSI @ 6 SPM (7 STROKES, 3012 PSI) 23:00 - 00:00 1.00 02 A DRILLING FLOAT COLLAR AND SHOE F/6490' TO 6541' (SHOE @ 6537' DPM) 00:00 - 00:30 0.50 02 A DRILLING F/6541' TO 6561. ART 1/4 HR. 00:30 - 01:00 0.50 29 CIRCULATE BOTTOMS UP FOR FORMATION INTEGRITY TEST @ 6561' 01:00-01:30 0.50 31 FIT TEST W/9.0 PPG @ 10.5 PPG TO 396 PSI 01:30 - 06:00 4.50 02 A DRILLING F/6561' TO 6754'. ART 2-1/4 HRS.; AST 1-1/2 HRS; ADT 4 HRS. 1/26/2001 - 06:00 - 12:00 6.00 02 A DRLIN2 DRLG. F/6754 T/7000. 12:00 - 13:00 1.00 02 A DRLIN2 DRLG. F/7000 T/7075. 13:00 - 13:30 0.50 07 DRLIN2 SERVICE RIG & TOP DRIVE. 13:30 - 00:00 10.50 02 A DRLIN2 DRLG. F/7075 T/7592. 00:00 - 06:00 6.00 02 A DRLIN2 DRLG. F/7592 T/7854. 1/27/2001 06:00 - 11:00 5.00 02 A DRLIN2 DRLG. F/7854 T/8053. 11:00 - 12:00 1.00 05 I DRLIN2 MIX & CIRC. SWEEP FOR POH. 12:00 - 13:30 1.50 05 I DRLIN2 CIRC. SWEEP, PUMP DRY JOB. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 9 of 21 Operations Summa Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From - To Hours Code cSoUdbei Phase Description of Operations 1/27/2001 13:30 - 16:30 3.00 06 !A DRLIN2 POH TO SHOE. TIGHT. 116:30-18:00 1.50 06 A 'DRLIN2 i@6741MKUPTD, BACK REAM & PUMP TOH TO SHOE. 18:00 - 19:00 1.00 07 I DRL N2 BLOW DN TD, ADJUST SERV LOOP & KELLY HOSE FOR RACKING IA i DRLIN2 19:00 - 20:00 1.00 06 PUMP DRY JOB, TOH TO 5303. 20:00 - 21:30 1.50 08 A DRLIN2 CLEAN DRIP PAN UNDER ODS PIPE RACK. OBM RUNNING.OUT. 21:30 - 23:30 2.00 06 A DRLIN2 TOH. 23:30 - 00:00 0.50 06 A DRLIN2 TOH BHA, LID MWD PROBE. 00:00 - 01:00 1.00 06 A DRLIN2 FLUSH SPERRY MTR, BRK BIT, STD BACK. 01:00 - 04:30 3.50 15 A DRLIN2 'TEST BOP RAMS, 250/4000. TEST CHOKE/KILL LINE VALVES 250/4000. 04:30 - 06:00 1.50 06 A DRLIN2 RIH. 1/28/2001 06:00 - 10:00 4.00 26 P/U DRILL PIPE. 10:00- 11:30 1.50 06 A RIH. 11:30 - 12:00 0.50 05 K FILL PIPE, BRK CIRC @ SHOE 6535. 12:00 - 12:30 0.50 05 I CBU 10' OUT OF SHOE. 12:30 - 13:30 1.00 06 A TIH T/7737. 13:30 - 15:00 1.50 03 A REAM F/7737 T/BOT. 15:00- 16:00 1.00 02 A DRLIN2 DRLG.F/ 8053 T/ 8113. 16:00- 16:30 0.50 07 SERV. RIG. 16:30 - 00:00 7.50 02 A DRLIN2 DRLG. F/8113 T/8320. 00:00 - 06:00 6.00 02 A DRLIN2 DRLG. F/ 8320 T/8470. 1/29/2001 06:00 - 08:00 2.00 02 DRLIN2 DRLG. F/8470 T/8491. 08:00 - 08:30 0.50 05 I DRLIN2 PUMP SWEEP, FOR SHORT TRIP. 08:30 - 10:00 1.50 06 DRLIN2 SHORT TRIP 6 STDS. T/8018. 10:00 - 10:30 0.50 02 A DRLIN2 DRLG. F/8491 T/8493. 10:30 - 12:00 1.50 08 A DRLIN2 WORK ON PUMP & CHANGE SHAKER SCREEN. 12:00 - 13:30 1.50 02 A DRLIN2 DRLG. F/8493 T/8519. 13:30 - 14:00 0.50 08 DRLIN2 CHANGE SWAB ON # 2 PUMP. 14:00- 17:00 3.00 02 A DRLIN2 DRLG. F/ 8519 T/ 8575. 17:00 ~ 17:30 0.50 07 DRLIN2 SERVICE RIG. 17:30 - 00:00 6.50 02 A DRLIN2 DRLG. F/8575 TI 8741. 00:00 - 06:00 6.00 02 A DRLIN2 DRLG. F/8741 T/8930 1/30/2001 06:00 - 12:00 6.00 02 A DRLIN1 DRLG. F/8930 T/9015. 12:00 - 13:00 1.00 02 A DRLIN1 DRLG. F/9015 T/9043. 13:00 - 13:30 0.50 07 DRLIN1 SERVICE RIG. 13:30 - 00:00 10.50 02 A DRLIN1 DRLG. F/9043 T/9251. 00:00 - 06:00 6.00 02 A DRLIN1 DRLG. F/9251 T/9355. 1/31/2001 .06:00 - 08:00 2.00 02 A DRLIN2 DRLG. F/9355 T/9392. i08:00- 09:30 1.50 29 DRLIN2 CIRC. BOT. UP. !09:30- 10:30 1.00 06 H DRLIN2 POH 15 STD. SHORTTRIP T/8,112. 10:30 - 12:00 1.50 06 H DRLIN2 RIH. 12:00 - 15:00 3.00 02 A DRLIN2 DRLG. F/9392 T/9415. 15:00 - 15:30 0.50 07 DRLIN2 SERVICE RIG. 15:30 - 18:00 2.50 02 DRLIN2 DRLG F/9415 T/9431. 18:00 - 19:30 1.50 05 I DRLIN2 CBU, MIX & PUMP PILL. 19:30 - 22:00 2.50 06 A DRLIN2 TOH 22:00 - 00:00 2.00 06 A DRLIN2 TOH TO 2219. 00:00 - 01:00 1.00 06 A DRLIN2 TOH 01:00 - 02:30 1.50 26 DRLIN2 LID MWD, CHANGE BIT, CHANGE STAB BLADE. 02:30 - 05:30 3.00 06 A DRLIN2 CHECK MWD, RIH. 05:30 - 06:00 0.50 09 DRLIN2 SLIP/CUT DRLG. LINE 2/1/2001 06:00 - 06:30 0.50 09 DRLIN2 CUT DRLG. LINE. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page lO of 21 Operations Sumrna Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Da Sub', . . . ........................................... te ! From - To Hours Code l ............. Co...d...e.....!i .......................................................................................................................... Phase Descr, pt,on of Operat,ons 2/1/2001 106:30 - 08:00 I 1.50 06 DRLIN2 ,08:00 - 08:30 0.50 03 A DRLIN2 I FILL PIPE, REAM 100' TO BOTTOM. 08:30 12:00 3.50 02 A DRLIN2 DRLG. F/9431 T/9472. '12:00 - 12:30 0.50 02 A DRLIN2 DRLG. F/9472 T/9477. 12:30 - 19:00 6.50 02 A DRLIN2 DRLG. F/9477 T/9606 19:00 - 19:30 0.50 08 E DRLIN2 TROUBLE SHOOT TOP DRIVE 19:30 - 00:00 4.50 02 A DRLIN2 . DRLG. F/9606 T/9669 00:00 - 06:00 6.00 02 A DRLIN2 DRLG F/9669 T/9825' 2/2/2001 06:00 - 16:30 10.50 02 A DRLIN2 'Drilling and surveying 8 1/2" hole. 16:30 - 17:30 1.00 29 DRLIN2 Pump hi-vis sweep and reciprocate pipe. 17:30 - 19:00 1.50 06 H DRLIN2 . Short trip to 9325'. Hole OK 19:00 - 04:30 9.50 02 A DRLIN2 i Pump hi-vis sweep. 04:30 - 06:00 1.50 02 A DRLIN2 :Drilling 8 1/2" hole. 2/3/2001 06:00 - 01:30 19.50 02 A DRLIN2 i Drilling and surveying 8 1/2" hole. 01:30 - 03:00 1.50 05 L DRLIN2 ' Circulate hi-vis sweep. Pump up survey, monitor well-pump pill. 03:00 - 06:00 3.00 06 A 'DRLIN2 ;POOH 2/4/2001 06:00 - 10:00 4.00 06 A DRLIN2 , POOH to BHA.Worked through tight spots from 7365' to 7085'. 10:00 - 11:00 1.00 06 A DRLIN2 Work BHA. 11:00 - 13:30 2.50 15 A DRLIN2 ~Test BOP to 4000 PSI. 13:30 - 16:00 2.50 26 DRLIN2 Lay down M/M, jars, HOC and probe. Pick up new M/M, jars, HOC and probe, RIH with rest of BHA. Test MWD and M/M on last stand of HWDP. 16:00 - 21:30 5.50 06 A DRLIN2 Pick up 48 joints of 5" DP off walk, RIH. 21:30 - 22:00 0.50 05 K DRLIN2 Circulate @ shoe. 22:00 ~ 22:30 0.50 06 A DRLIN2 RIH, tight @ 6769', make up Kelly. 22:30 - 23:30 1.00 03 DRLIN2 Ream through tight spot @ 6769' to 6860'. 23:30-01:00 1.50 06 A DRLIN2 RIH Ream last four stands from 10268' to 10541' 01:00 - 06:00 5.00 02 A DRLIN2 Drilling and surveying from 10541' to 10655'. 2/5/2001 06:00 - 01:00 19.00 02 A DRLIN2 Drill and survey 8 1/2" hole. 01:00 - 02:30 1.50 05 L DRLIN2 Pump hi-vis sweep, circulate hole clean for short trip, monitor well. 02:30 - 03:30 1.00 06 DRLIN2 Short trip from 11110' to 10548', 7 stands, no problems. 03:30 - 06:00 2.50 02 A DRLIN2 Drilling 8 1/2" hole. 2/6/2001 06:00 - 04:30 22.50 02 A DRLIN2 Drilling and surveying 8 1/2" hole from 11182' to 11674'. 04:30 - 05:30 1.00 05 DRLIN2 Circulate hole clean for short trip. 05:30 - 06:00 0.50 06 H DRLIN2 POOH for short trip. 2/7/2001 06:00 - 01:30 19.50 02 A DRLIN2 Drilling and surveying 8 1/2" hole. Begin sliding for turn and drop to hit target. 01:30 - 02:30 1.00 05 DRLIN2 Work tight hole after slide. Pull 360 K. to free pipe. 02:30 - 04:00 1.50 29 DRLIN2 Circulate hole clean to POOH. Monitor well. 04:00 - 06:00 2.00 06 A DRLIN2 POOH for new bit. 2/8/2001 06:00 - 07:30 1.50 06 A DRLIN2 POOH 07:30 - 09:30 2.00 05 DRLIN2 Work through tight spots from 7182' to 6720'. 09:30 - 12:30 3.00 06 A DRLIN2 POOH 12:30 - 14:00 1.50 26 DRLIN2 PJSM Work BHA. Lay down motor, pick up motor. Change out MWD. 14:00 - 14:30 0.50 06 A DRLIN2 RIH Stop at first stand of HWDP, change out saver sub. 14:30 - 15:30 1.00 08 I E DRLIN2 Replace top drive saver sub and dies. 15:30-16:00 0.50 06 A DRLIN2 RIH w/first stand of DP, test MWD. 16:00 - 18:30 2.50 06 A DRLIN2 RIH to shoe. 18:30 - 19:30 1.00 06 A DRLIN2 PJSM Cut and slip drilling line. 19:30 - 23:00 3.50 06 A DRLIN2 RIH Tight hole at 7024' to 7276'. 23:00 - 03:00 4.00 03 DRLIN2 Ream and survey from11581' to 11961'. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 11 of 21 Operations Summa Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From-To/ Hours/ Code cSoUdbe' Phase Description of Operations 2/8/2001 ' 03:00 - 06:00 i 3.00 02 IA I DRLIN2 Drilling (rotate and slide) from 11961' to 12016'. 2/9/2001 06:00 - 02:30 ' 20.50 02 'A ' DRLIN2 Drill (rotate and slide) and survey from 12016' to 12418'. 02:30 - 03:30 1.00 29 DRLIN2 Circulate bottoms up. Survey with MWD. Monitor well. 03:30 - 04:30 1.00 06 H DRLIN2 POOH to 11910', no problems. Break off top drive. 04:30 - 05:30 1.00 08 E DRLIN2 Change out swivel packing while circulating through head pin. 05:30 - 06:00 0.50 06 H DRLIN2 RIH to bottom. 2/10/2001 06:00 - 03:30 21.50 02 A DRLIN2 Drill and survey 8 1/2" hole. Slide and rotate for turn and drop. 03:30 - 04:30 1.00 02 DRLIN2 Survey, circulate bottoms up for trip out if hole. Monitor well, pump dry job. 04:30 - 06:00 1.50 06 A DRLIN2 POOH for bit 2/11/2001 06:00 - 10:00 4.00 06 J DRLIN2 Trip out of hole. 10:00 - 13:00 3.00 03 A DRLIN2 Ream out coal beds. 13:00 - 16:30 3.50 06 J DRLIN2 Trip out after dry job. 16:30 - 17:30 1.00 26 DRLIN2 Stand BHA back in derrick 17:30 - 20:30 3.00 15 A DRLIN2 Test Bop's 20:30 - 21:30 1.00 26 DRLIN2 Make up new bit, new full gauge stab. blades, new MWD probe. 21:30 - 00:00 2.50 06 A DRLIN2 Trip in the hole 00:00 - 03:00 3.00 06 A DRLIN2 Trip in the hole 03:00 - 06:00 3.00 03 A DRLIN2 Ream from the shoe @ 6535 to 7100' MD. Appears to be cleaning up 2/12/2001 06:00 - 06:30 0.50 03 A DRLIN2 Finish reaming coal beds below shoe. 06:30 - 09:30 3.00 06 A DRLIN2 Trip to 12325' MD. 09:30 - 12:30 3.00 03 A DRLIN2 Ream to bottom, due to possible undergauge hole. 12:30 - 00:00 11.50 02 A DRLIN2 Drilling ahead rotating, and sliding 1 40 foot set to knock angle down. 00:00 - 06:00 6.00 02 A DRLIN2 Drilling ahead watching for heavy oil shows. 2/13/2001 06:00 - 08:30 2.50 02 A DRLIN2 Drill to 13150' MD. 08:30 - 09:30 1.00 05 I DRLIN2 Circulate BU looking for C4's, and C5's on gas chromatograph. 09:30 - 12:30 3.00 02 A DRLIN2 Reach total depth @ 13200. Logging and casing point. 12:30 - 14:00 1.50 05 A DRLIN2 Circulate the hole clean. 14:00 - 22:30 8.50 06 H DRLIN2 Short trip. Tight spots 7276 and 7464' MD. 22:30 - 02:00 3.50 05 A DRLIN2 Pump sweep, weight up to 9.4 heavy. Circulate the hole clean. 02:00 - 06:00 4.00 06 C DRLIN2 Trip out of hole for logs. 2/14/2001 06:00 - 12:00 6.00 06 C DRLIN2 Trip out for logging 12:00 - 13:30 1.50 26 DRLIN2 Pull MWD probe, brak off bit, stand BHA back, clear rig floor. 13:30 - 14:00 0.50 11 A DRLIN2 Pre job safety meeting with Schlumberger. 14:00 - 17:00 3.00 11 A DRLIN2 Make up tools, calibrate, load sources. 17:00 - 06:00 13.00 11 A DRLIN2 Run two wireline suites. Platform express, and dip meter. 2/15/2001 06:00 - 07:30 1.50 11 A DRLIN2 Rig down Schlumberger 07:30 - 08:00 0.50 07 DRLIN2 Clean up rig floor after logging. 08:00 - 09:30 1.50 06 J DRLIN2 Lay down mud motor, hang off collar, make up clean out assembly. 09:30 - 12:00 2.50 06 J DRLIN2 Trip in with clean out assembly. 12:00 - 13:00 1.00 09 DRLIN2 Slip and cut 13:00 - 14:00 1.00 06 J DRLIN2 Lay down near bit reamer. 14:00 - 16:00 2.00 26 DRLIN2 Pick up Mud motor, new bit, hang off collar. 16:00 - 19:00 3.00 26 DRLIN2 Steam out and Strap 1000 feet of 5" drill pipe, service top drive 19:00 - 21:30 2.50 26 I DRLIN2 Load MWD probe, orient, trip in the hole with singles. Test MWD tool 21:30 - 22:30 1.00 08 DRLIN2 Fix broken hydraulic line on top drive. 22:30 - 05:30 7.00 06 DRLIN2 Trip to bottom 05:30 - 06:00 0.50 03 DRLIN2 Slow ream to bottom, warming up mud. Tag bottom at report time. 2/16/2001 06:00 - 14:00 8.00 02 A DRLIN2 Rotating ahead. Hole conditions good. Sands drill at 30 fi/hr. conglomerates down to 11 fi/hr. 14:00 - 14:30 0.50 07 DRLIN2 Adjust rubber protection on kelly hose/Top drive hose. 14:30 - 19:00 4.50 02 A DRLIN2 Rotating ahead, with two slides placed in the well bore. 19:00 - 19:30 0.50 03 A DRLIN2 Hung up momentarily while sliding, ream the hole, pump a sweep. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 12 of 21 Operations Summa Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date ' From- To Hours ] Code/.-Su.b ! Phase Description of Operations ~ I Iu°aei 2/16/2001 ]19:30 - 06:00 10.50 02 !A 'DRLIN2 J Rotating and sliding. Hole conditions good. Slow ream each stand. No , up reaming. Cut flow rates to 2/3rds normal flow when moving down to I keep from surging the coals. 2/17/2001 06:00 - 14:30 8.50 02 A DRLIN2 Rotating and sliding. 35,000 Wob, 480 Gpm, 85 Rpm, dropping angle. 14:30 - 15:30 1.00 05 A DRLIN2 Circulate bottoms up. 15:30 - 16:30 1.00 06 H DRLIN2 5 Stand short trip. 16:30 - 06:00 13.50 02 A DRLIN2 Drilling. surveying, connections. Sliding for angle drop into Westforelands. 2/18/2001 06:00 - 08:00 2.00 02 A DRLIN2 Drill to TD. 08:00 - 10:30 2.50 05 A DRLIN2 Circulate and condition mud system. The hole cleaned up after two full bottoms up. 10:30 - 21:00 10.50 06 H DRLIN2 Short trip into the casing. Monitor well. One spot from 7620 to 7799' MD had to be reamed to get back down through. 21:00 - 00:30 3.50 05 D DRLIN2 Circulate and condition mud for logging. 00:30 - 06:00 5.50 06 C DRLIN2 At report time @ the shoe. 6500' MD and pulling out to test BOP's. Then wireline logs. 2/19/2001 06:00 - 09:00 3.00 06 C Trip to shoe. Monitor well inside casing. Trip out to BHA 09:00 - 10:30 1.50 11 A Trip to the BHA. Stand back in the derrick. 10:30 - 11:00 0.50 07 Clean up rig floor. 11:00 - 12:00 1.00 15 A PJSM, pull wear ring, P/U test joint. 12:00 - 15:00 3.00 15 A Test BOP stack. 15:00 - 15:30 0.50 07 Clean up rig floor. 15:30 - 22:00 6.50 11 A Run wireline logs. 22:00 - 06:00 8.00 21 Evaluating wireline logs. Rig crews busy with mud pumps rig maintenance. 2/20/2001 06:00 - 11:00 5.00 21 DRLIN2 Service rig, waiting on final game plan for future of well bore. 11:00 - 21:30 10.50 06 F DRLIN2 Decide to place cement across Hemlock. Trip in the hole with 500 feet of 3.5" DP on bottom of 5" DP, to bottom. 21:30 - 02:00 4.50 05 H DRLIN2 Circulate and condition mud for balanced plugs. 02:00 - 03:00 1.00 05 H DRLIN2 Place 34 BBLs. Hi-Vis pill from 14009' MD to 13580' MD. 03:00 - 04:00 1.00 05 I H DRLIN2 Pull 10 stands slow, and CBU for cement job. 04:00 - 04:30 0.50 01 iA DRLIN2 Rig up DJ. Have pre job safety meeting with cementers. 04:30 - 06:00 1.50 12 C DRLIN2 Pump abandonment plug. 46.94 BBLs. of 15.8 ppg cement, followed by 225 BBLs. of Mud for balanced plug. 2/21/2001 06:00 - 07:00 1.00 12 C Cement BJ Cementing. 07:00 - 08:00 1.00 06 F Cement Trip out to 12671' MD. 08:00 - 08:30 0.50 12 C Cement Drop dart 08:30 - 13:30 5.00 06 F Cement Trip out of hole to shoe to wait on cement. 13:30 - 19:30 6.00 05 H Cement Circulate at a slow rate while waiting on cement. 19:30 - 21:30 2.00 06 F Cement Trip in the hole to 12581' MD 21:30 - 00:00 2.50 05 H Cement Circulate and condition mud. Wait on cement. 00:00 - 01:00 1.00 03 A Cement Ease to bottom looking for hard cement. Found the cement @ 13039' MD. 01:00 - 04:00 3.00 05 H Cement Circulate and condition mud. Some cement came back, 3 BBLs. and some sand. 04:00 - 06:00 2.00 12 C Cement Pump 20.5 bbls cement, 221 bbls mud. Cement in place at report time. 2/22/2001 06:00 - 07:00 1.00 06 F Cement Trip out of the hole to 12112' MD. 07:00 - 08:30 1.50 05 H Cement Drop dart CBU. 08:30 - 13:00 4.50 06 F Cement Trip out of the hole to shoe @ 6535' MD. 13:00 - 19:00 6.00 05 H Cement ~ Circulate hole clean. 2 bottoms up. Idle pump back from 500 gpm to 100 gpm while waiting on cement. 19:00 - 21:00 2.00 06 F Cement Trip in the hole to 12208' MD. 21:00 - 23:00 2.00 05 H Cement Circulate and condition mud 5 stands above cement plug. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 13 of 21 Operations Summa Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date "From - To J Hours Code (~oUdbe' Phase Description of Operations 2/22/2001 123:00 - 00:00 i 1.00 06 F Cement Trip in slow with pump stroking 14 spm. Tag cement top @ 12733' MD. , I Set 20,000k weight on bit. Hold for 5 minutes. Good cement. 00:00 - 02:00 2.00 06 F Cement I Trip out of the hole to 10650' MD. for gel spacer. 02:00 - 03:30 1.50 05 H Cement Circulate and condition. 03:30 - 04:30 1.00 05 H Cement Place 48.8 BBLs of gel/water spacer in hole, balanced from 10650 to 10150' MD. 04:30 - 06:00 1.50 05 H Cement We pulled up 10 stands, and circulated bottoms up with the stinger hanging at 9650' MD. 2/23/2001 06:00 - 07:00 1.00 05 H Cement CIRC. & PJSM W/BJ CEMENTERS & RIG CREW. BJ PUMPED 3 BBL. H20, TEST LINES T/3000 PSI, PUMP 7 BBLS. H20. 07:00 - 08:00 1.00 17 B Cement PUMP 35.3 BBLS. 17 PPG CEMENT, BJ DISPLACE WI 169 BBLS. MUD. 08:00 - 09:00 1.00 06 F Cement TOOH T/9217. 09:00 - 10:30 1.50 29 Cement DROP DP DART, CBU, PUMP DRY JOB. 10:30 - 13:00 2.50 06 F Cement TOOH. 13:00 - 13:30 0.50 06 F Cement MOVE HWDP & DC'S 'FO RHT. SIDE. 13:30 - 15:00 1.50 06 F Cement TOOH. 15:00 - 16:00 1.00 06 F Cement CHANGE OVER TO 3 1/2 EQUIP., LID 16 JTS. 3 1/2 D.P. 16:00 - 19:00 3.00 13 Cement CLEAN RIG FLOOR, WELDER CUT HOLE FOR BLOW DN. LINE. 19:00 - 20:30 1.50 26 Cement L/DN SPERRY M'I'R, MAKE UP NEW MTR, SET @ 1.5 DEG. 20:30 - 00:00 3.50 15 A Cement P/U TEST JT. PULL WEAR BUSHING, MK/UP FLOOR VALVE TEST BOP'S 250/4000 PSI. TEST BAG 250/3000 PSI, TEST KOOMEY. 00:00 - 01:00 1.00 15 A Cement FINISH TESTING BOP.BLOW DOWN, SET WEAR RING. 01:00 - 02:00 1.00 06 A Cement TIH BHA, TEST MWD. 02:00 - 06:00 4.00 06 A Cement TIH. 2/24/2001 06:00 - 07:00 1.00 06 F Cement TIH 07:00 - 10:00 3.00 03 A Cement TIH, SLOW LOOKIHG FOR CEMENT F/9785 T/10005. 10:00 - 10:30 0.50 02 I Cement DRLG. CEMENT F/10005 T/10029. 10:30 - 12:00 1.50 05 H Cement CIRC. HOLE CLEAN, MIX/PUMP DRY JOB. 12:00 - 13:30 1.50 06 F 'Cement TOOH. 13:30 - 17:30 4.00 06 F Cement TOOH, WORKING PIPE & BACK REAM, 7736, 7633, 7551 & 7182. PIPE FREED UP @ 7154'. 17:30 - 18:00 0.50 06 F Cement TOOH TO SHOE, PUMP DRY JOB. 18:00 - 20:30 2.50 06 F Cement TOOH. 20:30 - 21:30 1.00 06 F Cement TOOH W/HWDP & BHA, LID MWD PROBE & BRK BIT. 21:30 - 22:30 1.00 07 Cement : SERV. RIG, CLEAN RIG FLOOR. 22:30 - 23:00 0.50 06 F Cement !CIO ELEV. TO 3 1/2. DRIFT 3 1/2 DP P/U 16 JTS. 23:00 - 00:00 1.00 06 F Cement CHANGE ELEV. TIH. 00:00 - 04:00 4.00 06 F Cement TIH. 04:00 - 06:00 2.00 05 H Cement CIRC. & COND. MUD @ 10025. 2/25/2001 06:00 - 07:30 1.50 05 H Cement CIRC. & COND. MUD. @ 10,025. 07:30 - 08:00 0.50 12 C Cement PJSM., CEMENT JOB. 08:00 - 09:00 1.00 12 C Cement BJ CEMENTING. 09:00 - 09:30 0.50 06 F Cement PULL 10 STDS, 5 @ SLOW RATE. 09:30- 11:00 1.50 12 C Cement DROP DART, CBU, PUMP DRY JOB. 11:00- 12:00 1.00 06 F Cement TOH. 12:00 - 12:30 0.50 06 F Cement TOH TO SHOE. 12:30 - 14:30 2.00 06 F Cement MOVE HWDP TO ODS, TOH. 14:30 - 16:30 2.00 06 F Cement TOH W/3 1/2 DP, L/D SAME, CLEAN RIG FLOOR. 16:30 - 17:30 1.00 26 Cement MK UP BIT,CK ORIENTATE MWD, TIH W/HWDP. 17:30 - 19:30 2.00 06 F Cement TIH. 19:30 - 21:00 1.50 09 Cement CUT & SLIP DRLG. LINE, SERV. RIG. 21:00-23:00 2.00 06 IF Cement TIHT/9313, BRKCIRC. Printed: 511512001 3:24:18 PM FOREST OIL CORP. Page 14 of 21 Operations SummaBt Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End' Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From-To Hours/ Code/ S(~dbe Phase Description of Operations 2/25/2001 23:00 - 00:00; 1.00/ 06 '. F ~ Cement i CIRC. SLOW RATE TAG CMT PLUG @ 9,662. SET 20 K ON PLUG. I I I STAND BACK ONE STD. WORK PIPE & CIRC. 00:00 - 02:30 2.50 05 iH Cement CIRC. & COND. MUD. 02:30 - 03:00 0.50 03 A Cement GO TO BOT. SLOW LOOKING FOR HARD CEMENT F1 9662 T/9744. 03:00 - 06:00 3.00 05 H Cement CIRC. & WORK PIPE, WOC. 2/26/2001 06:00 - 09:00 3.00 13 Cement CIRC. WOC. 09:00 - 12:00 3.00 03 A Cement LOOKING FOR HARD CEMENT F/9738 T/9782. 12:00 - 13:30 1.50 03 A Cement LOOKING FOR HARD CEMENT F/9782 T/9820. 13:30 - 17:30 4.00 02 E Cement TIME DRLG. F/9820 TI 9855. (KICK OFF @ 9834 MD) 17:30 - 23:00 5.50 02 E DRLIN2 SLIDING F/9855 T/9925. 23:00 - 00:00 1.00 02 A DRLIN2 i ROTARY DRLG. F/9925 T/9957. 00:00 - 06:00 6.00 DRLIN2 i DRLG F/9957 TI 10042. 2/27/2001 06:00- 12:00 6.00 02 A DRLIN2 i DRLG. F/10,042 T/10,085. 12:00 - 13:30 . 1.50 02 A DRLIN2 DRLG. F/10,085 T/10,096. 13:30 - 15:00 1.50 29 DRLIN2 CIRCULATE, MIX / PUMP DRY JOB. 15:00 - 20:00 5.00 06 A DRLIN2 TOH, CIO GRABBER DIES ON TESCO TOP DRIVE. 20:00 - 21:00 1.00 06 A DRLIN2 TOH W/HWDP & BHA L/D MWD PROBE & BRK BIT. 21:00 - 22:30 1.50 26 DRLIN2 MK UP NEW BIT, ORIENTATE, P/U NEW HOC INSTALL PROBE & TEST MWD. 22:30 - 00:00 1.50 06 A DRLIN2 TIH 00:00 - 03:30 3.50 06 A DRLIN2 TIH T/9769. 03:30 - 05:30 2.00 03 A DRLIN2 BREAK CIRC., ORIENT TO GO THRU KOP. BACK REAM TO CLEAN OUT KOP. REAM TO BOTTOM. ,05:30 - 06:00 0.50 02 A DRLIN2 DRLG. F/10,096 T/10,110. 2/28/2001 ~06:00 - 12:00 6.00 02 A DRLIN2 DRLG. F/10,110 T/10,230. 12:00 - 00:00 12.00 02 A DRLIN2 DRLG. F/10,230 T/10,512. 00:00 - 06:00 6.00 02 B DRLIN2 DRLG. F/10,512 T/10,620. 3/1/2001 06:00 - 14:00 8.00 02 A DRLIN2 Drilling 8 1/2" hole. 14:00- 15:00 1.00 05 DRLIN2 Survey, CBU. 15:00 - 16:30 1.50 06 DRLIN2 10 stand short trip. No problems hole OK. 16:30 - 06:00 13.50 02 A DRLIN2 Pump hi-vis sweep after short trip while drilling. Drill from10731' to 10923'. 3/2/2001 06:00 - 09:00 3.00 02 A DRLIN2 Drilling 81/2' hole.(Rotate and slide.) 09:00 - 10:00 1.00 05 L DRLIN2 Pump Iow/hi-vis sweep. 10:00 - 21:30 11.50 02 A DRLIN2 Drill from 10955' to 11199'. (Rotate and slide.) 21:30 - 22:30 1.00 05 L DRLIN2 Pump Iow/hi-vis sweep, survey and record SPR. 22:30 - 06:00 7.50 02 DRLIN2 Drilling 8 1/2" hole from 11199' to 11310'. 3/3/2001 06:00 - 18:30 12.50 02 A DRLIN2 Drill and survey 8 1/2" hole. 18:30 - 22:00 3.50 05 DRLIN2 Pump Iow/hi-vis sweep, CBU, Pull 4 stands, CBU, monitor well, pump ! dry job. , 22:00 - 01:30 3.50 06 A DRLIN2 POOH, no problems. 01:30 - 02:00 0.50 07 DRLIN2 Pull to shoe @ 6520, monitor well, fill trip tank, blow down top drive. 02:00 - 04:30 2.50 06 A DRLIN2 POOH to BHA. 04:30 - 06:00 1.50 06 A DRLIN2 Work BHA. 3/4/2001 06:00 - 06:30 0.50 15 A DRLIN2 Rig up to test BOP. 06:30 - 09:30 3.00 15 A DRLIN2 Test all BOP equipment 250/4000 PSI. Hydril 250/3000 PSI. Rig down test equipment. 09:30 - 12:00 2.50 06 A DRLIN2 i Make up BHA.Lay down bit, motor and jars. Pick up new motor, jars and bit. Change out float. Change stab. on motor. Run HWDP. 12:00- 15:30 3.50 06 A DRLIN2 RIH 15:30 - 16:30 1.00 07 DRLIN2 Slip and cut drilling line. ~16:30 - 19:00 2.50 06 A DRLIN2 RIH Printed: 5/15/2001 3:24:18 PM ,., FOREST OIL CORP. Page,,15 of 21 Operations Summa Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 ,Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date ' From - To ~ Hours Code cSUdbei Phase Description of Operations 3/4/2001 i19:00 - 20:30 I 1.50 03 A I DRLIN2 'Ream last two stands from 11297' to 11484'. Circulate bottoms up. i ! Increase circulation to 500 gpm as mud warms up and viscosity decreases. 20:30 - 06:00 9.50 02 !iA DRLIN2 Drilling and surveying 8 1/2' hole from 11484' to 11669'. (Rotate and I slide) 3/5/2001 06:00 12:30 6.50 02 A DRLIN2 Drill and survey 8 1/2" hole from 11669' to 11786'. 12:30 - 13:30 1.00 05 L DRLIN2 Circulate Iow/hi-vis sweep. 13:30- 01:30 12.00 02 A DRLIN2 Drilling 8 1/2" hole from 11786' to 12043'. 01:30 - 03:00 1.50 05 L DRLIN2 Rotate and reciprocate while pumping Iow/hi-vis sweep. 03:00 - 04:00 1.00 06 H DRLIN2 Short trip from 12043' to 11391'. 04:00 - 06:00 2.00 02 A DRLIN2 Drilling 8 1/2" hole from 12043' to 12095'. 3/6/2001 06:00 - 13:00 7.00 02 A DRLIN2 Drill and survey 8 1/2" hole from 12095' to 12233'. (Rotate and slide). 13:00 - 15:00 2.00 05 L DRLIN2 Circulate Low/hi-vis sweep to reduce torque. Survey w/MWD. SPRs. 15:00 - 01:30 10.50 02 A DRLIN2 Drill and survey 8 1/2" hole from 12233' to 12391'. (Rotate and slide). 01:30 - 03:00 1.50 05 DRLIN2 CBU, hole clean, mix dry job. Monitor well, pump dry job. 03:00 - 06:00 3.00 06 A DRLIN2 Tight hole @ 11516' to 11454'. Pull 45K over. 3/7/2001 06:00 - 08:00 2.00 06 A DRLIN2 POOH to shoe, monitor well, service rig and fill trip tank. 08:00- 10:30 2.50 06 A DRLIN2 IpOOH 10:30 - 12:00 1.50 06 A DRLIN2 ~Work BHA, break off bit. 12:00- 12:30 0.50 06 A DRLIN2 RIH 12:30 - 13:00 0.50 06 A DRLIN2 Service top drive. Test MWD and HOC. 13:00 - 19:00 6.00 06 A DRLIN2 RIH. Fill pipe @ 30 stds. Ream and circ. through tight spot @ 7587' to 7597'.RIH 19:00 - 20:30 1.50 03 DRLIN2 Ream from from 12234' to 12391'. 20:30 - 22:00 1.50 05 DRLIN2 Circ. Iow/hi-vis sweep. 22:00 - 06:00 8.00 02 A DRLIN2 Drill 8 1/2" hole from 12391' to 12543'. Trouble getting survey after first conn. 3/8/2001 06:00 - 12:00 6.00 02 A DRLIN2 DRLG. F/12543 T/12663. 12:00 - 17:00 5.00 02 A DRLIN2 DRLG. F/12663 T/12797. 17:00 - 17:30 0.50 05 A DRLIN2 CIRCULATE. 17:30 - 19:00 1.50 02 A DRLIN2 DRLG. F/12797 T/12827. 19:00 - 21:00 2.00 05 I DRLIN2 CIRCULATE. 21:00 - 00:00 3.00 02 A DRLIN2 DRLG. F/12827 T/12905. 00:00 - 02:00 2.00 02 A DRLIN2 DRLG. F/12905 T/12950. 02:00 - 02:30 0.50 05 A DRLIN2 CBU/SURVEY. 02:30 - 04:30 2.00 05 I DRLIN2 PUMP LOW / HI VIS SWEEP, CIRC. HOLE CLEAN. PUMP DRY JOB. 04:30 - 06:00 1.50 06 C DRLIN2 TOH. 3/9/2001 06:00- 12:00 6.00 06 C DRLIN2 TOH. 12:00 - 15:30 3.50 06 C TOH, BHA. LAY DOWN STABS,LEAD COLLAR, MUD MOTOR, BREAK BIT. 15:30 - 17:00 1.50 11 A EVAL 2 PJSM, RIG UP SCHLUMBERGER. 17:00 - 00:00 7.00 11 A EVAL 2 RIH & LOG W/SCHLUMBERGER QUAD COMBO.RIG DOWN LOGGERS. 00:00 - 02:30 2.50 26 DRLIN2 PJSM. M/U CLEAN OUT ASSY F/WIPER RUN. 02:30 - 05:30 3.00 06 H DRLIN2 TIH T/6497, FILL PIPE. @ 3600'. 05:30 - 06:00 0.50 09 DRLIN2 CUT & SLIP DRLG LINE & CIRC. :3/10/2001 06:00 - 07:00 1.00 09 CSGIN2 SLIP & CUT DRLG. LINE. 07:00 - 11:00 4.00 06 H CSGIN2 TIH T/12,861, FILL PIPE. 11:00 - 11:30 0.50 03 A CSGIN2 PRECAUTIONARY REAM TO 12,950. 11:30 - 12:00 0.50 05 L CSGIN2 PUMP SWEEP, CBU. 12:00 - 16:30 4.50 05 F CSGIN2 CIRC. SWEEP, MONITOR WELL, PUMP PILL. 16:30 - 22:00 5.50 06 H ~CSGIN2 TOH TO SHOE. 22:00 - 23:00 1.00 05 F CSGIN2 CIRCULATE. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 16 of 21 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From - To Hours Code cSoUdbe~ Phase Description of Operations 3/10/2001 23:00 - 00:00 :~ 1.00' 06 H CSGIN2 00:00 - 02:30 2.50 06 IH CSGIN2 TIH TI 12,950. 02:30 - 04:00 , 1.50 05 I CSGIN2 CBU, MONITOR WELL, PUMP DRY JOB. 04:00 - 06:00 2.00 06 H CSGIN2 TOH T/RUN CSG. 3/11/2001 06:00- 12:00 6.00 06 G CSGIN2 TOH, SLM. 12:00- 14:00 2.00 06 G CSGIN2 TOH. 14:00 - 17:30 3.50 06 G CSGIN2 LID HWDP & BHA, USE VAC TRUCK. 17:30 - 19:00 1.50= 15 A CSGIN2 PULL WEAR RING, CHANGE BOTTOM PIPE RAMS T/7 5/8, TEST DOOR SEALS T/3,000 PSI. 19:00 - 19:30 0.50 25 CSGIN2 INSTALL WEAR RING. 19:30 - 21:00 1.50 12 B CSGIN2 RIG UP STABBING BOARD. 21:00 - 00:00 3.00 12 B CSGIN2 RIG UP CSG TOOLS, CSG TONG BROKE, L/D & P/U NEW SET. 00:00 - 00:30 0.50 12 CSGIN2 PJSM T/RUN 7 5/8. 00:30 - 02:00 1.50 12 CSGIN2 M/U FLOAT SHOE, 80' SHOE TRACK. 02:00 - 06:00 4.00 12 A CSGIN2 RIH WITH 7 5/8 LINER. 3/12/2001 06:00 - 12:00 6.00 12 B CSGIN2 RIH W/7 5/8 LINER. 12:00 - 15:00 3.00 12 B CSGIN2 RIH W/7 5/8 LINER. 15:00 - 18:00 3.00 12 B CSGIN2 L/D CASING EQUIP. P/U BAKER HANGER. M/U TESCO SAVOR SUB & BELL. 18:00- 19:00 1.00 05 F CSGIN2 CIRC. LINER. 19:00- 20:30 1.50 12 B CSGIN2 !L/D STABBING BOARD. 20:30 - 21:00 0.50 12 B CSGIN2 M/U CEMENT HEAD. 21:00 - 21:30 0.50 25 CSGIN2 PJSM ON RABBITING DRILL PIPE, RIH. 21:30 - 00:00 2.50 12 B CSGIN2 RIH W/7 5/8 LINER ON DP. 00:00 - 06:00 6.00 12 CSGIN2 RIH W/7 5/8 LINER ON DP.FILL PIPE EVERY 10 STANDS 3/13/2001 06:00 - 12:00 6.00 12 B CSGIN2 BREAK CIRC. @ 12,815, P/U 1 PUP JT & 1JT DP W/CEMENT HEAD. 12:00 - 12:30 0.50 05 F CSGIN2 CIRC. & COND. HOLE @ 12,947, WORK PIPE. 12:30 - 15:30 3.00 05 F CSGIN2 DROP 1 3/4 BALL, CIRC. DOWN. RELEASE HR TOOL. 15:30 - 17:00 1.50 12 C CSGIN2 PJSM. CEMENT 7 5/8 LINER. 17:00 - 18:00 1.00 12 C CSGIN2 DISPLACE W/RIG PUMPS T/BUMP PLUG. DID NOT BUMP. 18:00- 18:30 0.50 08 E CSGIN2 CIRC. 18:30 - 20:30 2.00 05 H CSGIN2 REPLACE DIES IN TOP DRIVE CLAMP. 20:30 - 21:00 0.50 25 CSGIN2 BLOW DN TOP DRIVE. PJSM. 21:00 - 00:00 3.00 06 G CSGIN2 TOH L/D DRILL PIPE. 00:00 - 05:00 5.00 06 G CSGIN2 TOH L/D DRILL PIPE. L/D BAKER RUNNING TOOL. 05:00 - 06:00 1.00 06 CSGIN2 TIH W/15 STD DP F/DERRICK & L/D. L/D CMT CIRC. HEAD. 3/14/2001 06:00 - 09:00 3.00 06 G CSGIN2 FINISH LAYING DOWN 5" DP. 09:00 - 09:30 0.50: 12 D CSGIN2 CLEAN RIG FLOOR. 09:30 - 10:30 1.00 15 A CSGIN2 PULL WEAR RING, SET TEST PLUG. 10:30 - 11:30 1.00 14 B CSGIN2 C/O BOTTOM SET OF RAMS F/7 5/8 T/3 1/2. 11:30 - 12:00 0.50 15 A CSGIN2 PJU T/TEST BOP. 12:00 - 13:00 1.00 14 B CSGIN2 REPLACE RAM DOOR SEALS 13:00 - 18:00 5.00 15 =A CSGIN2 TEST BOP. TOPDRIVE ACC BALL VALVE FAILED. GOOD TEST ON REST OF BOP. 18:00 - 19:00 1.00 07 CSGIN2 CHANGE OUT ACC. BALL VALVE ON TOPDRIVE. 19:00 - 19:30 0.50 15 C CSGIN2 RIG UP AND TEST IBOP. 19:30 - 20:00 0.50 15 A CSGIN2 RIG DOWN TEST EQUIPMENT AND BLOW DOWN ALL LINES. 20:00 - 00:00 4.00 26 CSGIN2 PICK UP AND STRAP 3-1/2" DRILLPIPE 00:00 - 06:00 6.00 26 CSGIN2 RIH WITH 176 JTS. OF 3-1/2" DRILLPIPE 3/15/2001 06:00 - 09:30 3.50 06 J CSGIN2 FINISH PICKING UP 3 1/2 DP.( 267 JTS). 09:30 - 10:00 0.50 07 CSGIN2 RESET TORQUE VALUES ON TOP DRIVE. 10:00 - 11:00 1.00 05 CSGIN2 CIRC. THRU 3 1/2 DP. 11:00 - 12:00 1.00 31 CSGIN2 TEST 7 5/8 CSG. T/3,000 PSI. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 17 of 21 Operations Summa Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 I ' Date From- To Hours Code I,,S,,u2,, Phase ] Description of Operations 3/15/2001 112:00 - 12:30 0.501 28 i CSGIN2 'PUMP DRY JOB. 12:30 - 17:30 5.00 06 J ICSGIN2 TOH 17:30- 18:00 0.50 25 ICSGIN2 CLEAN RIG FLOOR. 18:00 - 19:00 1.00 26 CSGIN2 R/U SPERRY SUN DEPTH ENCODER. 19:00 - 23:00 4.00 26 CSGIN2 P/U BHA, ORIENT, INSTALL SOURCE. 23:00 - 00:00 1.00 06 A CSGIN2 RIH, TEST SPERRY TOOLS @ 5 STDS IN. 00:00 - 02:30 2.50 06 A CSGIN2 ~TIH W/3 1/2 DP T/6200. 02:30 - 03:00 0.50 05 A CSGIN2 :CIRC. 03:00 - 05:30 2.50 06 A CSGIN2 TIH W/3 1/2 T/7512. CONT. TIH W/5 1/2. 05:30 - 06:00 0.50 05 A CSGIN2 CIRC. @ 12700. 3/16/2001 06:00 - 06:30 0.50 05 I DRLIN2 i ClRCULATE. 06:30 - 07:00 0.50 06 J DRLIN2 TIH T/12870. 07:00 - 12:00 5.00 02 D DRLIN2 DRLG. LANDING COLLAR, FLOAT SHOE T/12,949. 12:00 - 15:00 3.00 02 D DRLIN2 DRLG. FLOAT SHOE & CLEAN OUT 12,950. 15:00 - 17:00 2.00 02 DRLPRO TIME DRLG. F/12,950 T/12,970. 17:00 - 17:30 0.50 05 A DRLPRO CIRCULATE. 17:30 - 18:00 0.50 32 DRLPRO FIT @ 589 PSI. EQ. MD WT. 10.5. 18:00 - 00:00 6.00 02 A DRLPRO SLD. F/12790 T/13010. 00:00 - 06:00 6.00 02 A DRLPRO SLD. F/13010 T/13065. 3/17/2001 06:00 - 07:30 1.50 02 A DRLPRO DRILL F/13065 T/13073. 07:30 - 08:30 1.00 05 I DRLPRO CIRC. PUMP DRY JOB. 08:30 - 09:30 1.00 06 J DRLPRO ITOH, LID 3 JTS. 09:30 - 10:00 0.50 08 B DRLPRO ~C/O GRABBER DIES ON TOP DRIVE. 10:00 - 11:30 1.50 06 J DRLPRO 'TOH, WET. 11:30 - 12:00 0.50 28 DRLPRO PUMP DRY JOB. 12:00 - 16:00 4.00 06 J DRLPRO TOH, WET. 16:00 - 16:30 0.50 08 E DRLPRO WORK ON PIPE SPINNERS, LAY DOWN SPINNERS. 16:30 - 19:00 2.50 06 J DRLPRO TOH. 19:00 - 20:30 1.50 06 J DRLPRO BHA, HOLD PJSM W/SPERRY. REMOVE NUKES, BRK BIT. SET MOTOR BACK T/0 DEG. LID. 20:30 - 21:30 1.00 26 DRLPRO P/U NEW MOTOR NEW MOTOR SET BEND @ 2.12, INSTALL KICK PAD & SHIM. 21:30 - 23:00 1.50 06 J DRLPRO CLEAN RIG FLOOR, WHILE DOWNLOAD MWD. HANG REPAIRED PIPE SPINNERS. 23:00 - 00:00 1.00 DRLPRO PJSM, LOAD NUKES. 00:00 - 00:30 0.50 26 DRLPRO PULSE TEST MWD TOOL. 00:30 - 04:00 3.50 06 J DRLPRO TIH w/3-1/2" DP to 7544' 04:00 - 05:00 1.00 06 J DRLPRO CIO 3-1/2" elevators to 5"; P/U 3 jts. 5"; set in derrick 05:00 - 06:00 1.00 09 DRLPRO PJSM. Cut and slip drilling line. 3/18/2001 06:00 - 06:30 0.50 08 C :DRLPRO SERVICE RIG. 06:30 - 09:30 3.00 06 J DRLPRO TIH, FILL PIPE. 09:30 - 10:30 1.00 03 A DRLPRO PRECAUT, WASH T/B F/12952 T/13073. 10:30 - 12:00 1.50 02 A DRLPRO SLD. F/13073 TI 13080. 12:00 - 00:00 12.00 02 A DRLPRO SLD. F/13080 T/13180. 00:00 - 05:00 5.00 02 A DRLPRO SLD F/13180 T/13196. 05:00 - 06:00 1.00 05 A DRLPRO CBU. 3/19/2001 06:00 - 07:00 1.00 05 A DRLPRO CBU. 07:00- 07:30 0.50 06 J DRLPRO TOH TO SHOE. 07:30 - 08:00 0.50 28 DRLPRO DROP ROD, OPEN PUMP OUT SUB, PUMP DRY JOB. 08:00 - 11:30 3.50 06 J DRLPRO TOH. (WET) 11:30- 12:00 0.50 07 ! DRLPRO CLEAN RIG FLOOR. 12:00 - 13:00 1.00 06 i J DRLPRO CLEAN RIG FLOOR. MIX, PUMP DRY JOB. 13:00- 16:00 3.00 06 J DRLPRO TOH. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 18 of 21 Operations Surnma Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date i From-To'Hours Coder~,,~..Sub Phase ' ' I BHA, REMOVE SOURCES, BRK BIT. SET MOTOR BEND TO 1.5. 311912001 116:00 - 19:00 I 3.00 06 J DRLPRO : ~ ~ DN/LOAD MWD. 19:00 - 20:30 1.50 06 [i J DRLPRO 'LOAD SOURCES, TIH, TEST MWD & CHECK PUMP OUT SUB. 20:30 - 00:00 3.50 06 J DRLPRO TIH. 00:00 - 03:30 3.50 06J DRLPRO TIH, FILL DP @ 10,990. 03:30 - 06:00 2.50 06 J DRLPRO TIH, ORIENT T/HIGH SIDE, PREC. REAM F/13,134 T/BTM. 3/20/2001 06:00- 12:00 6.00 02 A DRLPRO SLIDE F/13,195 T/13,230. 12:00 - 16:30 4.50 02 A DRLPRO SLIDE F/13,230 T/13,246. 16:30 - 18:30 2.00 05 I DRLPRO MWD LOST SIGNAL, ATTEMPT TO GET BACK,CIRC. 18:30 - 20:00 1.50 06 J DRLPRO TOH TO SHOE, BACK REAM & PUMP TIGHT AREA @ 13,012. 20:00 - 20:30 0.50 28 DRLPRO DROP BAR, OPEN CIRC. SUB, PUMP DRY JOB. 20:30 - 00:00 3.50 06 J DRLPRO TOH, LID TOP JT. OF 5", WASHED OUT.TOH. 00:00 - 03:30 3.50 06 J DRLPRO TOH, LID JARS. 03:30 - 05:00 1.50 06 J DRLPRO PJSM, DOWN LOAD MWD's, UNLOAD SOURCE. 05:00 - 06:00 1.00 06 J DRLPRO LID BHA. 3/21/2001 06:00 - 06:30 0.50 06 A DRLPRO Finish laying down BHA. 06:30 - 07:00 0.50 15 A DRLPRO PJSM on R/U and testing BOPs. 07:00 - 08:30 1.50 15 A DRLPRO Pull wear bushing, Rig up and test BOPs. 08:30 - 11:00 2.50 15 A DRLPRO Test all rams, upper and lower kelly cock, 5" & 3 1/2" floor safety valves, choke manifold, kill and choke lines to 250/4000 PSI. Pressure tested annular preventer to 250~3000 PSI. 11:00 - 12:00 1.00 15 A DRLPRO Blow down choke manifold wtht air to pits. Rig down test equipment and set wear bushing. 12:00 - 14:30 2.50 06 A DRLPRO PJSM Review procedure. Pick up MWD, pony collar and Mud Motor. Make up bit. Pick up one jt. HWDP and jars. 14:30 - 15:00 0.50 06 A DRLPRO Make up circ. sub and one stand 3 1/2" DP and test MWD. 15:00 - 15:30 0.50 06 A DRLPRO TIH with 3 1/2" DP. Fill pipe @ 3500' intervals. 15:30 - 16:00 0.50 08 B DRLPRO Change out kick roller ODS, when servicing rig and crown. 16:00 - 18:00 2.00 06 A DRLPRO TIH with 3 1/2" DP. 18:00 - 21:00 3.00 06 A DRLPRO Change elevators to 5", adjust spinner for5". TIH with 5". Lay down bottom single on stand #51(washed out). TIH to shoe. 21:00 - 22:00 1.00 06 A DRLPRO Break circulation, orient high side. TIH to bottom. 22:00 - 00:00 2.00 02 A DRLPRO Orient and slide from 13246' to 13261'. 00:00 - 06:00 6.00 02 A DRLPRO Drilling new hole from 13261' to 13289'. 3/22/2001 06:00 - 23:00 17.00 02 A DRLPRO Drill 6 3/4" hole from 13289' to 13354'. 23:00 - 00:00 1.00 05 DRLPRO Circ., mix dry job. 00:00 - 00:30 0.50 05 DRLPRO Finish CBU, orient to high side, monitor well. 00:30- 01:00 0.50 06 A DRLPRO POOH to 12949'. 01:00 - 01:30 0.50 06 A DRLPRO Monitor well, drop by-pass spear and pump down, pump dry job. 01:30 - 04:00 2.50 06,~ DRLPRO POOH to 7708'. 04:00 - 04:30 0.50 06 DRLPRO Change out elevators to 5", change out stripping rubber and slips, adjust spinners to 3 1/2". 04:30- 06:00 1.50 06 A DRLPRO POOH. 3/23/2001 06:00 - 07:30 1.50 06 A DRLPRO POOH Lay down two jts. 3 1/2" DP (in string). 07:30 - 09:00 1.50 06 A DRLPRO POOH w/BHA. Lay down by-pass sub and non-mag pony collar, HOC and MWD. 09:00 - 10:30 1.50 06 A DRLPRO Break bit, make up new 6 3/4" bit. pick up DGR/DIR/REG,NUKES and HOC. 10:30 ~ 12:00 1.50 06 A DRLPRO PJSM Down load MWD, install Nuke source. 12:00 - 13:00 1.00 06 A DRLPRO Review TIH procedures, finish loading Nuke source, make up circ. sub. 13:00 - 16:30 3.50 06 A DRLPRO TIH with 3 1/2" DP, fill pipe @ 3500' intervals. 16:30 - 17:00 0.50 06 A DRLPRO Change elevators, rig air slipsand fill pipe. 17:00 - 19:00 2.00 06 A DRLPRO TIH with 5" DP to shoe. Fill pipe. I Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 19 of 21 Operations Sumrna Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From - To Hours Code (~o~"e[ Phase Description of Operations 3/23/2001 i 1.00 07 I DRLPRO Review cut and slip drlg. line and man riding procedurs. Cut and slip 19:00 - 20:00 ~ II ~ drlg. line. 20:00 - 21:00 i 1.00 06 A DRLPRO I Attemt to get toolface to orient high side. MWD tool not updating. 21:00 - 22:00 1.001 06 A DRLPRO I TIH two stands, to 13230'. Work on getting good toolface. No toolface 'updates. 22:00 - 00:00 2.00 06 A DRLPRO MADD pass from13245' to 13300'. 00:00 - 01:00 1.00 10 E DRLPRO Attemt to pump up tool face(MWD). 01:00 - 01:30 0.50 02 A DRLPRO Drilling from 13354' to 13359'. 01:30 - 02:00 0.50 10 E DRLPRO Circulate, look for tool face. No tool face. 02:00- 02:30 i 0.50 06 DRLPRO POOH to shoe. 02:30 - 03:00 0.50 10 DRLPRO Try to survey, no results. Drop p.o.s., pump dry job. 03:00 - 06:00 3.00 06 DRLPRO Monitor well, POOH. 3/24/2001 06:00 - 09:00 3.00 06 J DRLPRO POOH. 09:00 - 10:00 1.00; 10 E DRLPRO Testing MWD @ jars. Tested OK. 10:00 - 12:00 2.00 06 J DRLPRO Work BHA. Download MWD. 12:00 - 14:00 2.00~ 06 J DRLPRO Scribe motor. Upload MWd, load Nukes, Test MWD and visually check jars and P.O.S. for leaks. Lay down 3 1/2" single. 14:00 - 17:00 I 3.00 06 J DRLPRO TIH w/16 stds. 31/2" DP.Pulse test MWD. OK. TIH. 17:00 - 18:00 1.00 06 J DRLPRO Pulse test MWD. OK. Change over to 5" slips etc. 18:00 19:00 1.00 06 J DRLPRO TIHw/10stds. 5" DP. TestMWd. OK. 19:00 - 20:00 1.00 10 E DRLPRO Test MWD. 20:00 - 23:00 3.00 06 J DRLPRO TIH 10 stds. Test MWD. Ok TIH. Test MWD every 10 stds. 23:00 - 00:00 1.00 06 J DRLPRO Pump up survey @ shoe. Having trouble due to noise. 00:00 - 01:30 1.50 10 E DRLPRO Trying to get MWD toolface @ shoe, unable to get toolface. 01:30 - 02:00 0.50 05 H DRLPRO Mix dry job, drop P.O.S. dart, pump dry job. 02:00 - 03:30 1.50 06 J DRLPRO POOH. 03:30 - 04:00 0.50 07 DRLPRO Change over to 3 1/2" tools. 04:00 - 06:00 2.00 06 J DRLPRO POOH. 3/25/2001 06:00 - 07:30 1.50 06 J DRLPRO POOH. 07:30 - 10:30 3.00 06 J DRLPRO Work BHA. Lay down DGR/DIR/RES-Nukes-HOC. Pick up pony collar-New Hoc and 6 3/4" bit. 10:30 - 12:00 1.50 06 J DRLPRO RIH. Test MWD @ jars. OK. 12:00 - 12:30 0.50 07 DRLPRO Service rig. 12:30 - 15:00 2.50 06 J DRLPRO TIH w/3 1/2" DP. Fill pipe @ 3500' intervals and pulse test MWD. Change elevators to 5". 15:00 - 18:30 3.50 06 J DRLPRO Pulse test MWD. TIH and pulse test MWDevery 3500' and @ shoe. TIH to bottom. 18:30 - 00:00 5.50 02 A i DRLPRO Break circ. Orient and slide from 13359' to 13386'. 00:00 - 06:00 6.00 02 A DRLPRO Drilling 6 3/4" hole from 13386' to 13435'. (Rotate and slide). 3/26/2001 06:00 - 22:00 16.00 02 A DRLPRO Drilling and surveying 6 3/4" hole. Sliding to drop angle. 22:00 - 00:00 2.00 05 DRLPRO Circulate condition hole. 00:00 - 00:30 0.50 06 A DRLPRO POOH to shoe. 00:30 - 01:30 1.00 28 DRLPRO Monitor well. Pump P.O.S. dart. Pump dry job. 01:30 - 02:30 1.00 06 A DRLPRO POOH with 5" DP. 02:30 - 03:00 0.50 06 A DRLPRO Change over slips etc. to pull 3 1/2" DP. 03:00 - 06:00 3.00 06 A DRLPRO POOH. 3/27/2001 06:00 - 06:30 0.50 06 A DRLPRO POOH w/3 1/2" DP. 06:30 - 07:30 1.00 06 A DRLPRO Work BHA, break out bit. 07:30 - 08:30 1.00 06 A DRLPRO Break out and lay down BHA. 08:30 - 09:00 0.50 07 DRLPRO Service rig.. 09:00 - 10:30 1.50 06 A DRLPRO Make up new BHA, new bit, lay down pony collar, pick up stab and thruster. Test MWD. 10:30- 12:00 1.50 06 A DRLPRO RIH. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Operations Summary Report Page 20 of 21 Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From -To Hours Code '~Su.b i Phase Description of Operations 3/27/2001 12:00 - 14:00 2.001 06 :'A DRLPRO TIH wi 3 1/2" DP. Pulse test MWD @ 3500'. OK. Record pressure. 14:00 - 14:30 0.50i 06 IA DRLPRO Change over to 5: equipment. Fill pipe and pulse test MWD. Record i pressure. 14:30 - 16:30 2.00 06 A DRLPRO TIH to shoe. 16:30 - 17:30 1.00 07 DRLPRO Review cut and slip procedure. Cut and slip 100' of drilling line. 17:30 - 18:00 DRLPRO Orient high side, RIH. Wash last 60' to bottom. 18:00 - 00:30 DRLPRO Orient and slide drill from 13480' to 13515'. 00:30 - 04:30 DRLPRO Tesco top drive Fwd. control and drill mode disabled. Rigged manual by-pass. 04:30 - 06:00 DRLPRO Re-orient and slide drill to 13517'. 3/28/2001 06:00 - 21:30 DRLPRO Drilling from 13515' to 13643'. (Slide and Rotate). 21:30 - 23:30 'DRLPRO Pump Iow/hi-vis sweep. Reciprocate and rotate. CBU 23:30 - 02:00 DRLPRO Drlg. from 13643' to 13656'. 02:00 - 02:30 i DRLPRO POOH to 7 5/8" shoe. 02:30 - 03:30 DRLPRO Monitor well for 10 min. Pump P.O.S. dart. Fill trip tank. Pump dry job. 03:30 - 06:00 DRLPRO POOH with 5" DP. 3/29/2001 06:00 - 08:30 DRLPRO POOH 08:30 - 10:00 DRLPRO Break bit- BHA-pump diesel through motor, blow down. 10:00 - 12:00 DRLPRO Read pre-job procedures. Test BOP. 12:00 - 13:00 DRLPRO Finish testing bottom rams (3 1/2") 250/4000 psi. Break and lay down test joint. Pick up 5" jt., run and set wear bushing. Blow down choke manifold. 13:00 - 14:30 DRLPRO Set motor to 0 deg. Lay down motor, pick up new motor and set to 1.15 deg. Make up bit. RIH first stand of 3 1/2" Dp. Test MWD. OK. 14:30 - 17:00 DRLPRO TIH with 3 1/2" DP. 17:00 - 17:30 DRLPRO Fill pipe, change over to 5" equipment. 17:30 - 19:30 DRLPRO TIH to shoe, pulse check MWD. TIH to 13421,Tight hole. 19:30 - 20:30 DRLPRO Kelly up, wash and ream from 13421' to 13425'. Precautionary wash and ream last 56'. Pump up survey. 20:30 - 06:00 DRLPRO Drilling 6 3/4" hole from 13656' to 13744'. 3/30/2001 06:00 - 00:00 DRLPRO Drilling 6 3/4" hole. (Rotate and slide.) 00:00 - 00:30 DRLPRO Ream last slide. Hugh torque. 00:30 - 01:00 DRLPRO Trying to drill, POOH due to hugh torque. 01:00 - 03:30 DRLPRO Pumped Iow/hi-vis sweep. Circulate hole clean. 03:30 - 04:30 DRLPRO POOH to shoe. No hole problems. Drop dart, monitor well. Calibrate Sperry-Sun. Pump dry job. 04:30 - 06:00 DRLPRO POOH from shoe. 3/31/2001 06:00- 10:30 DRLPRO POOH 10:30 - 12:00 DRLPRO Work BHA. 12:00 - 13:00 DRLPRO Break motor and lay down. Pick up motor, BHA 331. Pick up DGR/DIR/RES. 13:00 - 13:30 DRLPRO Service rig and top drive. 13:30 - 20:30 DRLPRO Install Battery and finish picking up BHA. Charge with source. PJSM Change out HCIM tool. Program nukes. 20:30 - 00:00 DRLPRO RIH, fill pipe @ 40 stands. Test LWD tool. 00:00- 01:00 DRLPRO RIH 01:00 - 01:30 DRLPRO Change over to 5" handling tools, fill pipe. 01:30 - 02:30 DRLPRO RIH to 7 5/8" shoe. 02:30 - 03:30 DRLPRO Cut and slip drlg. line. 03:30 - 04:00 DRLPRO Test LWD. 04:00 - 06:00 DRLPRO Orient to high side. RIH to 13747'. Ream to bottom. 4/1/2001 06:00 - 07:30 DRLPRO DRLG. FI 13,857 T/13,871. 07:30 - 09:00 DRLPRO ATTEMPT TO PUMP SURVEY. NO SURVEY. Printed: 511512001 3:24;18 PM FOREST OIL CORP. Page 21 of 21 Operations Sumrna Report ,, ~ Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG DRILLING Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date'i From - To Hours Code cSoub" Phase Description of Operations 4/1/2001 09:00 - 12:00 3.001 02 iA DRLPRO DRLG. F/13,871 T/13,909. 12:00 13:00 1.00~ 02 A DRLPRO DRLG. F1 13,871 TI 13,917. 13:00 - 19:00 6.00 10 E DRLPRO MADD PASS TI 13,917. 19:00 - 19:30 0.50 06 J DRLPRO TOH T/SHOE. 19:30 - 20:00 0.50 28 DRLPRO MONITOR WELL, PUMP DART, PUMP PILL. 20:00 - 00:00 4.00 06 J DRLPRO TOH. 00:00 - 02:00 2.00 06 J DRLPRO TOH. (1 HR. DAYLIGHT SAVINGS TIME) 03:00 - 06:00 3.00 26 DRLPRO REMOVE SOURCE, DN LOAD LWD, L/D DM, P/U DIM. 4/2/2001 06:00 - 08:30 2.50 26 DRLPRO LOAD UP LWD, TEST MWD. 08:30 - 10:00 1.50 06 J DRLPRO TIH. 10:00 - 10:30 0.50 05 K DRLPRO FILL PIPE, TEST MWD. 10:30 - 12:00 1.50 06 J DRLPRO TIH, TEST MWD. 12:00 - 15:30 3.50 06 J DRLPRO TIH. 15:30 - 16:00 0.50 03 A DRLPRO REAM 80' T/BOT. 16:00 - 00:00 8.00 02 A DRLPRO DRLG. F/13,917 T/13975. 00:00 - 06:00 6.00 02 A DRLPRO DRLG. F/13,917 T/14,040. 4/3/2001 06:00 - 12:00 6.00 02 A DRLPRO DRLG. F/14,040 T/14078. 12:00 - 14:30 2.50 02 A DRLPRO DRLG. F/14078 T/14089. 14:30- 15:00 0.50 05 L DRLPRO CIRC. UP SWEEP. 15:00 - 18:00 3.00 02 A DRLPRO ' DRLG. F/14,089 T/14,099. 18:00 - 18:30 0.50 10 E DRLPRO CIRC., SURVEY, MIX DRY JOB. 18:30 - 20:00 1.50 06 A DRLPRO TOH TO SHOE. 12,950. 20:00 - 20:30 0.50 28 DRLPRO DROP DART, PUMP PILL. 20:30 - 00:00 3.50 06 A DRLPRO TOH. 00:00 - 02:30 2.50 06 A DRLPRO TOH. ~02:30 - 06:00 3.50 26 DRLPRO PJSM. PULL SOURCE, DN LOAD LWD, MK UP BIT # 29. 4/4/2001 06:00 - 08:00 2.00 26 DRLPRO TEST MUD MOTOR,MWD,LWD. 08:00 - 13:30 5.50 06 A DRLPRO TIH. 13:30 - 14:00 0.50 05 K DRLPRO BRK CIRC. TEST MWD TOOLS. 14:00 - 15:00 1.00 09 DRLPRO SLIP/CUT DRLG. LINE. 15:00- 16:00 1.00. 06 A DRLPRO TIH. 16:00 - 16:30 0.50 03 A DRLPRO REAM F/14,013 T/14,099. 16:30 - 00:00 7.50 02 A DRLPRO DRLG. F1 14,099 TI 14,210. 00:00 - 06:00 6.00 02 A DRLPRO DRLG. F/14,099 T/14,210. 4/5/2001 06:00 - 15:30 9.50 02 A DRLPRO DRLG. F/14,210 T/14273 15:30- 16:00 0.50 05 A DRLPRO CIRC. 16:00 - 18:30 2.50 06 A DRLPRO TOH T/SHOE. 18:30 - 19:30 1.00 08 E DRLPRO POP WET STD, CLEAN RIG FLOOR. 19:30 - 20:00 0.50 28 DRLPRO DROP DART, PUMP DRY JOB. 20:00 - 21:30 1.50 06 A DRLPRO TOH. (WET) 21:30 - 22:00 0.50 28 DRLPRO PUMP 2ND DRY JOB. 22:00- 00:00 2.00 06 A DRLPRO TOH 00:00 - 03:30 3.50 06 A DRLPRO TOH 03:30 - 06:00 2.50 06 J DRLPRO FLUSH BHA W/MAPCO, LID BHA. Printed: 5/15/2001 3:24:18 PM FOREST OIL CORP. Page 1 of 7 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG COMPLETION Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 ~ Sub I · Date From - To Hours ] Code ,-,A.,.. Phase ~ Description of Operations .............................. L .................... I__ .............. ! ................... L.?.~_~_L .................... L .......................................................................................................................................................... 06:00 4/5/2001 - 15:30 9.50 02 .A DRLPRO DRLG. F/14,210 T/14273 15:30 16:00 0.50 05 'A 'DRLPRO CIRC 16:00 - 18:30 2.50 06 A DRLPRO TOH T/SHOE. 18:30 - 19:30 1.00 08 E DRLPRO POP WET STD, CLEAN RIG FLOOR. 19:30 - 20:00 0.50 28 DRLPRO DROP DART, PUMP DRY JOB. 20:00 - 21:30 1.50 06 A DRLPRO TOH. (WET) 21:30 - 22:00 0.50 28 DRLPRO PUMP 2ND DRY JOB. 22:00 - 00:00 2.00 06 A DRLPRO TOH 00:00 - 03:30 3.50 06 A DRLPRO TOH 03:30 - 06:00 2.50 06 J DRLPRO FLUSH BHA W/MAPCO, LID BHA. 4/6/2001 06:00 - 07:00 1.00 06 A DRLPRO FINISH LAYING DOWN BHA. 07:00 - 10:30 3.50 15 A DRLPRO PRESSURE TEST BOP 250/4000. HYDRILL 250/3000. 10:30 - 11:30 1.00 26 DRLPRO MAKE UP BHA FOR CLEAN OUT RUN. 11:30- 12:00 0.50 06 H DRLPRO TIH. 12:00 - 19:00 7.00 06 H DRLPRO TIH, TI 12,950. 19:00 - 00:00 5.00 03 A DRLPRO REAM F/13,042 T/13,150. WORK PIPE & JAR OUT OF HOLE. 00:00 - 00:30 0.50 06 J DRLPRO TOH 00:30 02:30 2.00 05 I DRLPRO CIRC, DROP DART, PUMP DRY JOB. 02:30 - 06:00 3.50 06 H DRLPRO TOH. 4/7/2001 06:00 - 10:30 4.50 06 J DRLPRO TOH 10:30 - 11:00 0.50 06 J DRLPRO LID STABILIZER & HOLE OPENER. 11:00 - 12:00 1.00 26 DRLPRO M/U MOTOR, 6 3/4" BIT,TIH. 12:00 - 17:30 5.50 06 J DRLPRO TIH 17:30 - 18:30 1.00 09 DRLPRO SLIP / CUT DRLG. LINE. 18:30 - 19:30 1.00 06 J DRLPRO TIH F/SHOE. 19:30 - 23:30 4.00 05 L DRLPRO PUMP SWEEP, CBU, SPOT 60 BBL. MAPCO PILL F/14,273 T/ 12,750. 23:30- 00:00 0.50 06 H DRLPRO TOH. SLM. 00:00 - 01:00 1.00 06 H DRLPRO TOH ,TI 12,688. 01:00 - 02:00 1.00 28 DRLPRO DROP DART, PUMP DRY JOB. 02:00 - 06:00 4.00 06 H DRLPRO TOH. SLM. 4/8/2001 06:00 - 10:30 4.50 06 G CSGPRO TOH 10:30 - 13:00 2.50 33 CSGPRO PJSM. LID BHA. 13:00 - 15:00 2.00 26 CSGPRO P/U 24 JTS HWDP, STD BACK IN DERRICK. 15:00 - 16:00 1.00 12 B CSGPRO RIG UP CSG CREW. 16:00 - 19:30 3.50 12 B CSGPRO TIH W/46 JTS 4 1/2" SLOTTED LINER. 19:30 - 21:00 1.50 12 B CSGPRO P/U LINER HGR, CIRC THRU LINER & HGR. 21:00 - 03:30 6.50 12 B CSGPRO TIH W/DP, HGR & LINER. 03:30 - 04:00 0.50 12 B CSGPRO REPOSITION 22 STDS 3 1/2 DP IN DERRICK. 04:00 - 06:00 2.00 12 B CSGPRO TIH W/DP, HGR & LINER. 4/9/2001 06:00 - 08:30 2.50 12 B CSGPRO TIH WITH DP/LINER @ 3MIN STD. '08:30 - 09:30 1.00 05 F CSGPRO CIRC. & COND. MUD @ SHOE. 09:30 - 10:30 1.00 12 B CSGPRO TIH, TAG BOT. @ 14,273. 10:30 - 12:30 2.00 12 D CSGPRO DROP 1 7/16" KIRKSITE BALL, ALLOW T/GRAVITATE T/SEAT, 12:30 - 13:30 1.00 12 D CSGPRO SET LINER HGR / PACKER. SET LINER 1 FT OFF BOT. @ 14,272'. 13:30 - 00:00 10.50 06 G CSGPRO TOH, SIDEWAYS. SUPER SUCKER OIL BASE FROM DP. 00:00 - 06:00 6.00 06 G CSGPRO TOH, SIDEWAYS. 4/10/2001 06:00 - 06:30 0.50 22 RIH with excess 3 1/2" DP from derrick. 06:30 - 08:30 2.00 22 Continue with laying down 3 1/2" DP. 08:30 - 09:00 0.50 22 PJSM, change out pipe spinners. 09:00 - 12:00 3.00 22 POOH, lay down 3 1/2" DP. 12:00 - 12:30 0.50 22 Lay down Baker running tool. 12:30 - 13:30 1.00 07 Clean rig floor, lub. rig. Printed: 5/15/2001 3:23:51 PM FOREST OIL CORP. Page 2 of 7 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG COMPLETION Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From - To] Hours Code/ cSoUdbe~ Phase Description of Operations : , 4/10/2001 !13:30 - 15:00 I 1.50' 15 i i Change bottom rams to 2 7/8", test to 3000 psi. Good test. 15:00 - 00:00 9.00 i 'Load pipe racks with 2 7/8" tubing, strap and rabbit. Vac truck cleaning out slop tank and cellar. Clean oil base mud from BOP and cellar area. Monitor well. 00:00 - 04:00 4.00 Monitor well while drifting and strapping 2 7~8" tubing. 04:00 - 06:00 2.00 Rig up tubing equipment and tools for running 2 7/8" tubing. 4/11/2001 06:00 - 06:30 0.50 !PJSM Pick up Baker seal assembly, one joint 2 7/8" tubing, jet pump i cavity with standing valve and gauges. 06:30 - 01:00 18.50 RIH with Baker seal assembly on 2 7/8" tubing to 12811' 01:00 - 02:30 1.50 Unable to make up top drive to tubing due to leaking hydraulic hose. Replace hydraulic hose. 02:30 - 04:00 1.50 Finish running 2 7/8" tubing. Insert Baker seal assembly in seal bore recepticle. Pick up 2 1/2' for tubing expansion. 04:00 - 06:00 2.00 Attempt to bundle test to 3000psi. Test failed. 4/12/2001 06:00 - 09:00 3.00 05 F Circulate bottoms up. 09:00 - 12:00 3.00 25 Attempt to pressure test to 3000 psi. No test. Reposition seal assembly i to same depth, no test. ,12:00 - 13:00 1.00 05 Circulate. 13:00 - 13:30 0.50 Attempt to pressure test. No test. 13:30 - 00:00 10.50 06 POOH with 2 7~8" tubing. 00:00 - 01:00 1.00 Lay down pump cavity and seal assembly. 01:00 - 01:30 0.50 Make up dummy seal assembly. 01:30 - 02:00 0.50 07 Clean rig floor. 02:00 - 06:00 4.00 06 RIH with 2 7/8" tubing. 4/13/2001 11:30 - 12:00 0.50 15 Rig up to test. 12:00 - 14:30 2.50 Attempt to pressure Baker seal assembly, no test. 14:30 - 01:00 10.50 06 POOH with 2 7/8" tubing. 01:00 - 01:30 0.50 07 Clean rig floor. 01:30 - 02:30 1.00 PJSM Rig up to test BOPs. Make up 2 7/8" for testing with X-Os. Make up 5" test jt. for testing. 02:30 - 05:00 2.50 15 PJSM Test all rams, upper and lower Kelly valves, 5" and 2 7/8" floor valves, choke manifold and kill lines, 250/4000 psi. Pressure tested annular preventer to 250/3000 psi. 05:00 - 06:00 1.00 15 Rig down test equipment. Blow down choke manifold with air. 4/14/2001 06:00 - 08:30 2.50 07 PJSM Slip on 100' of drlg. line on drum, adjust and re-set COM. 08:30 - 09:00 0.50 07 Service rig, crown bocks, swivel, draw-works and brakes. 09:00 - 10:00 1.00 07 Clean rig floor. 10:00 - 11:00 1.00 06 Change out Iocator sub and seal assembly. 11:00 - 19:30 8.50 06 RIH with 2 7/8" tubing. (SLM) 19:30 - 21:30 2.00 Attempt to test packed seal assembly. No test. 21:30 - 06:00 8.50 05 Circulate- Wait on Baker packer. 4/15/2001 106:00 - 12:30 6.50 05 Circulating, while rigging up Pollard wireline services. 12:30 - 16:00 3.50 1'1 Finish rigging up wireline, RIH w 1 1/2" tools, spang jars, stem 1.9 swage to 12400'. 16:00 - 17:00 1.00 11 POOH w/wireline and rig down Pollard. 17:00 - 18:00 1.00 08 4" mud line on kelly leaking. Repair same. Pump pill. 18:00 - 18:30 0.50; 06 Change collar on first stand. 18:30 - 03:30 9.00 06 POOH with 2 7/8" tubing. Lay down seal assembly. 03:30 - 04:00 0.50 25 PJSM to test pump cavity, installed dummy standing valve and dummy pump. 04:00 - 04:30 0.50 i Test pump cavity to 1500 psi. Good test. 04:30 - 05:00 0.50 Rig down test equipment. X/Os, one jt. 2 7/8" tubing. 05:00 - 05:30 0.50 Make up Baker packer, one jr. 2 7/8" tubing and pump cavity. Printed: 5/15/2001 3:23:51 PM ,., FOREST OIL CORP. Page 3 of 7 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG COMPLETION Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 / Date From - To / Hours Code C~(~d"e Phase ~ Description of Operations J 4/15/2001 105:30 - 06:00 0.501 06 I RIH with 2 7~8" tubing. 4/16/2001 06:00 - 17:00 11.00 06 I I RIH with 2 7/8" tubing and packer assembly. 17:00 - 18:30 1.50 I~ Space out with 5.72' 2 7~8" tubing pup on bottom of tubing hanger. 18:30 - 22:30 4.00 ~ Attempt to set Baker packer @ 12814.07'. Did not set. 22:30 - 23:00 0.50 Mix and pump pill. 23:00 - 00:00 1.00 POHH with tubing hanger, break out and lay down hanger. POOH wi 27~8" tubing. 00:00 - 06:00 6.00 POOH with 2 7/8" tubing and packer assembly. (wet) Rabbit each stand. 4/17/2001 06:00 - 08:30 2.50 06 TOH WI 2 7~8" TUBING. 08:30 - 09:00 0.50 ATTEMPT TI CIRC. & PUMP DRY JOB. 09:00 - 09:30 0.50 CLEAN RIG FLOOR. 09:30- 12:00 2.50 06 TOH. 12:00- 17:30 5.50 TOH. 17:30 - 18:00 0.50 LID PUMP CAVITY, INSPECT PUMP BLANK & STANDING VALVE. 18:00 - 18:30 0.50 CLEAN RIG FLOOR. 18:30 - 19:30 1.00 MAKE UP PUMP CAVITY & TEST T/1,500 PSI FOR 5 MIN. GOOD TEST. 19:30 - 06:00 10.50 TIH. 4/18/2001 06:00 - 08:00 2.00 06 TIH W/2 7~8" TUBING & PACKER. 08:00 - 09:00 1.00 M/U LANDING JT, LAND HANGER T/12,814 FT. 09:00 - 09:30 0.50 SET BAKER PACKER @ 12,792 W/3,000 PSI. 09:30 - 10:00 0.50 PRES. TEST BACK SIDE, HOLD 3,000 PSI FOR 15 MIN. NO LEAK OFF. 10:00 - 10:30 0.50 RIG DN TEST EQUIP. & WEATHERFORD. 10:30 - 11:00 0.50 RIG UP POLLARD. 11:00 - 12:00 1.00 RIG MECHANIC REPAIRED BRAKES ON POLLARD WlRELINE UNIT. 12:00 - 18:00 6.00 RIH W/ WlRELINE, LATCH ONTO TUBING STOP. ATTEMPT TO JAR FREE. WlRELINE PARTED. 18:00 - 21:30 3.50 WAIT ON SPOOL OF WlRELINE. 21:30 - 23:30 2.00 ATTEMPT T/JAR DOWN TO SHEAR RELEASE ON ROPE SOCKET. 23:30 - 00:00 0.50 M/U & DROP KANLEY WlRELINE CUTTER. 00:00 - 02:00 2.00 ALLOW WlRELINE CUTTER TI GRAVITATE DOWN. N/G. 02:00 - 03:30 1.50 DROP ADDITIONAL WEIGHT BAR. 03:30 - 06:00 2.50 WORK WlRELINE, ATTEMPT TO PULL/CUT WIRE. N/G. WlRELINE PULLED FREE, W/DRAG. POH W/TBG STOP & CUTTER. WlRELINE PARTED. 4/19/2001 06:00 - 08:30 2.50 11 F POH W/ WlRELINE, LINE PARTED. ( 3RD TIME ) 08:30 - 10:30 2.00 PJSM. RIG UP, PULL SLACK IN WlRELINE W/AIR TUGGER. SPLICE LINE TO DRUM. 10:30 - 12:00 1.50 POH W/WlRELINE, LID ALL TOOLS & TUBING STOP. 12:00 - 21:00 9.00 CHANGE OUT LINE ON POLLARD WlRELINE UNIT. RIG WELDER & MECH. WORKING ON REPAIRS. REPAIRED DRIVE HUB, WELD HANDLE ON LINE GUIDE, WELD BRACKET TO UNSPOOL LINE. 21:00 - 00:00 3.00 P/U WlRELINE TOOLS, RIH TO RETREIVE PUMP BLANK. 00:00 - 06:00 6.00 RIH W/WlRELINE, ATTEMPT TO LATCH ON TO PUMP BLANK. 4/20/2001 06:00 - 08:00 2.00 11 RIH W/WlRELINE,LATCH ONTO PUMP BLANK, ATTEMPT TO POH.C/O WlRELINE WEIGHT INDICATOR. 08:00 - 09:00 1.00 POH WI WlRELINE, WlRELINE PARTED (4TH)'SHUT DOWN OPERATIONS. 09:00 - 12:00 3.00 WAIT ON POLLARD SUPERVISOR & PARTS. 12:00 - 13:30 1.50 SPLICE WlRELINE, CIO LOAD CELL ON WT. IND., INSPECT Printed: 5/15/2001 3:23:51 PM FOREST OIL CORP. Page 4 of 7 Operations Summa Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG COMPLETION Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Sub . . Date 1' From - To I Hours Code Code~ Phase Description of Operations 13:30 - 14:00 0.50' ] REV. CIRC. @ 500 PSI, ATTEMPT TO POH, WlRELINE PARTED. ( I ' 5TH) 14:00 - 18:00 4.00 ~ SPLICE LINE, POH, MADE 10', LINE PARTED. (6TH) 18:00 - 19:30 1.50 INSTALL PUMP IN SUB, REV. CIRC. W/RIG PUMP. PRES. UP TO 800 PSI. FREE ...... POH, SLOWWW. 19:30 - 00:00 4.50 POH W/WlRELINE WHILE RV. CIRC. L/D POLLARD TOOLS & PUMP BLANK. 00:00 - 01:00 1.00 RIG DOWN WIRE LINE T/UNSPOOL BAD LINE. 01:00 - 06:00 5.00 REV. CIRC. WHILE CHANGING OUT LINE ON POLLARD UNIT. 4/21/2001 06:00 - 08:30 2.50 11 :REV. CIRC. WHILE CHANGING OUT POLLARD WIRE LINE. 08:30- 10:30 2.00 i RIG UP, RIH W/WlRELINE. 10:30 - 11:00 0.50 !ATTEMPT TO PRES. UP ON TUBING, UNABOLT CLAMP ON I LUBRICATOR LEAKING. POH T/REPAIR. 11:00 - 14:00 3.00 I RIH W/WlRELINE T/STANDING VALVE. (12,781 WlRELINE MEAS.) WORK LINE. 14:00 - 15:30 1.50 REV. CIRC. WHILE POH. DRY RUN, INSPECT PULL TOOL. 15:30 - 17:00 1.50 RIH, WHILE CIRC. DN TUBING. 17:00 - 18:00 1.00 POH. DRY RUN. INSPECT PULLING TOOL. 18:00 - 20:00 2.00 MODIFY PULLING TOOL & INSTALLED CENTRALIZER ABOVE STANDING VALVE PULLING TOOL. ClRC/RIH. 20:00 - 20:30 0.50 CIRC DN. TBG, WHILE WORKING WlRELINE. 20:30 - 21:30 1.00 POH WHILE REV. CIRC WITH DUMMY STANDING VALVE. 21:30 - 00:00 2.50 RIH ON EQUALIZER RUN OF KX STANDING VALVE. PUMPING ;TOOLS DN. 00:00 - 01:30 1.50 ! POH WHILE REV. CIRC. DRY RUN 01:30 - 03:00 1.50 ' RIH, PUMPING TOOLS DN. 03:00 - 04:00 1.00 :PRES. WELL T/200PSI WHILE JARRING DN, LOOKING FOR PRES.CHANGE. 04:00 - 05:30 1.50 POH WHILE REV. CIRC. DRY RUN. 05:30 - 06:00 0.50 SERV. RIG. 4/22/2001 06:00 - 08:30 2.50 11 RE-TIE ROPE SOCKET. (24 TURNS TORSION TEST) RIH W/ EQUALIZER PRONG WHILE CIRC. DN TBG. 08:30 - 11:30 3.00 WORK WlRELINE WHILE CIRC. ATTEMPT TO KNOCK OUT LOCK. 11:30 - 12:00 0.50 RIG UP TO PUMP TOOLS OUT OF HOLE. 12:00 - 12:30 0.50 POH. DRY RUN. 12:30 - 14:30 2.00 P/U 5' WEIGHT BAR & KNUCKLE JT. MODIFY EQUALIZER PRONG. RIH. 14:30 - 15:30 1.00 WORK WlRELINE / CIRC. 15:30 - 16:30 1.00 POH. DRY RUN. 16:30 - 17:30 1.00 R/U W/1 1/4" OD X 4' BAILER. 17:30 - 20:30 3.00 RIH & WORK BAILER. POH W/SAMPLE F/12,854 WL MEAS. 12.3 MW SAMPLE. VIS ABOVE 300. 20:30 - 00:00 3.50 R/U TO DISPLACE W/CRUDE. PJSM W/PROD. REVERSE CIRC TO DISP. @ 3 1/2 BPM. 00:00 - 02:30 2.50 FINISH DISPLACEMENT. 770 BBL. PUT 77 BBLS IN PILL PIT FOR WlRELINE WORK. 02:30 - 05:00 2.50 R/U WlRELINE, RIH W/KNOCK OUT PRONG, TAG & WORK LINE. POH CHECK PRONG FOR MARKS. 05:00 - 06:00 1.00 R/U BAYLOR, RIH. 4/23/2001 06:00 - 08:00 2.00 11 BALING F/STD. VLV WHILE REV. CIRC. 08:00 - 10:30 2.50 POH. P/U MULE SHOE BAILER, RIH. TAG & TAKE SAMPLE. POH 10:30 - 12:00 1.50 RIH WI GS PULLING TOOL, WITHOUT DOGS T/12,830. POH. DID ~. Printed: 511512001 3:23:51 PM FOREST OIL CORP. Page 5 of 7 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG COMPLETION Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date i From-To,Hours [ Code cS~dbe i Phase, Description of Operations 4/23/2001 110:30 - 12:00 1.50 i ' NOT SHEAR 12:00 - 13:30 1.50 i ] RIH W/1.9 IMPRESSION BLOCK TO SAME. POH. NO IMPRESSION. 1 3:30 - 16:00 2.50 ; ] RIH W/1 1/2" BAILER W/FLAPPER TO 12,830. WORK LINE. POH. ] I (SMALL AMOUNT OF BARITE/SAND RECOVERED) 16:00 - 17:00 1.00 ~ RIH WI 1 3/4" IMPRESSION BLOCK TO SAME. POH IMPRESSION I OF FISHING NECK. 17:00 - 19:00 2.00 I RIH W/1 3/4" HYDROSTATIC BAILER TO SAME. POH. NO RECOVERY 19:00-21:00 2.00 RIH W/HYDRO BAILER & 1 3/4" SHOE. POH, BBL PACKED W/ SOLIDS. 21:00 - 22:30 1.50 RIH W/GS PULLING TOOL WI OUT DOGS.WORK LINE. POH R/D GS TOOL. DRY RUN. 22:30 - 00:00 1.50 RIH W/HYDRO BAILER. WORK LINE. POH. DISC DID NOT SHEAR. DRY RUN. 00:00 - 02:30 2.50 RIH W/PUMP BAILER. POH. BAILER FULL OF BARITE SLUDGE. 15.3 LB/GAL. 02:30 - 04:30 2.00 'RIH W/HYDRO BAILER. POH. RECOVER MORE BARITE SLUDGE. 04:30 - 06:00 1.50 ~RIH W/HYDRO BAILER. POH. RECOVER MORE BARITE SLUDGE. 4/24/2001 06:00 - 07:30 1.50 POH W/WlRELINE. RIH W/KNOCK OUT PRONG. 07:30 - 09:00 1.50 R/U & REVERSE CIRC. 09:00 - 10:00 1.00 RIH W/HYDROSTATIC BAILER. 10:00 - 11:30 1.50 REV. CIRC. WHILE BAILING F/12,830 WLMD. 11:30 - 12:30 1.00 POH. BAILER PACKED W/SOLIDS. 12:30 - 13:30 1.00 RIH W/HYDRO. BAILER. POH. NO RECOVERY 13:30 - 15:30 2.00 R/U & RIH W/GS TOOL. POH. DID NOT SHEAR. 15:30 - 17:00 1.50 RIH W/HYDROSTATIC BAILER W/SNORKLE TUBE. POH. RECOVERED BARITE SLURRY. 17:00 - 19:00 2.00 RIH W/HYDROSTATIC BAILER. POH. DID NOT SHEAR. 19:00-21:30 2.50 TIE NEW ROPE SOCKET. RIH W/GS TOOL ( 1 3/4" OD ) TO PULL STD VLV. TOOL STOPPED 32 FT OFF STD VLV @ 12,797 WLMD. WORK LINE, POH. 21:30 - 02:00 4.50 3 TRIPS W/BAILER. RECOVER SMALL AMOUNTS OF BARITE SLURRY EACH RUN. 02:00 - 04:30 2.50 RIH WITH HYDRO BAILER W/MODIFIED SNORKLE. POH. RECOVER BARITE SLURRY. GOOD MARKINGS ON SNORKEL. 04:30 - 06:00 1.50 RIH W/HYDRO BAILER. WORK LINE. 4/25/2001 06:00 - 08:00 2.00 11 RIH W/GS TOOL, SET DOWN ON X-LOCK, SHEAR JDC. POH. 08:00 - 12:00 4.00 R/U JDC. RIH. JAR UP ON STANDING VALVE. SHEAR JDC. POH ( 2 ROUND TRIPS) 12:00 - 14:30 2.50 RIH. LATCH ON X-LOCK, JAR DOWN & SHEAR. POH. 14:30 - 16:00 1.50 RIH W/JDC. LATCH & POH W/GS & STEM. 16:00 - 18:00 2.00 RIH W/KOBE STD VLV. POH 18:00- 21:00 3.00 TEST LINES, BUNDLE TEST T/2,000 PSI FOR 10 MIN. GOOD TEST. 21:00 - 00:00 3.00 R/U TO PUMP JET PUMP. DROP PUMP, PUMP T/SEAT. SEATED @ 2200 HRS. PUMP @ 3,000 PSI T/2300 HRS. INCREASE PRES. T/ 4,000 PSI. 00:00 - 06:00 6.00 PUMPING WELL @ 4,000 PSI. FLUSHING LINES & CLEANING PITS. 4/26/2001 06:00 - 17:30 11.50 FLOW WELL. FLUSHED CHOKE MANIFOLD, STACK, TD, MUD PUMPS & STAND PIPE W/MAPCO. CLEANING MUD PITS & MUD CLEANING EQUIP. 17:30 - 19:30 2.00 SHUT IN WELL. BLEED PRES F/LINES. REMOVE BLIND FLANGE ON MUD CROSS, T/CLEAN OUT OBM ON TOP OF TBG HGR. RIG DOWN CHICKSANS/HARD LINE, LANDING JT. INSTALL BPV. Printed: 5/15/2001 3:23:51 PM FOREST OIL CORP. Page 6 of 7 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 Event Name: ORIG COMPLETION Start: 12/13/2000 End: ~Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date ~ From - To Hours / Code cSoUdbe Phase Description of Operations 4/26/2001 19:30 - 06:00 r 10.50 ! ! PJSM. REMOVE DRIP PANS, NIPPLE DOWN, WASH EXCESS OBM I F/EQUIPMENT. 4/27/2001 06:00 - 12:00 6.00 30 PJSM on nippling down BOPs. Nipple down BOP. Put kill line hose on top of water tank- Take out lower rams, clean and grease, take out double stud XO, XO spool-mud cross, double gate and hydril. Rig up to set tree- Make up tree. 12:00 - 15:00 3.00 Pull back pressure valve. Run two way check valve. Test tree to 5000 psi. Clean pits and slop tank. Retrieve two way check valve after using Vac truck to vacum off above it. 15:00 - 00:00 9.00 01 B Rig down Tesco top drive while cleaning pits. 00:00 - 04:30 4.50 01 B Finish rigging down Tesco top drive. 04:30 - 05:00 0.50 01 B Slip on drilling line. Lay down swivel. 05:00 - 06:00 1.00 01 B Rig down derrick lines, Clear rig floor. Release rig. 4/28/2001 06:00 - 12:00 6.00 01 B RDMO Lay down swivel. Rig down degaser systems. Take shaker extension building off. Remove draw-works blower covers. Prepare windwalls to fold down. Rig down geolograph line, wireline. 12:00 - 00:00 ~ 12.00 01 B RDMO Rig down windwalls and flowlines. Prepare derrick for laying over. Lay ~ derrick on derrick stand. 00:00 ~ 06:00 ! 6.00 01 B RDMO Finish blowing down steam lines, drain boilers. Shut down three i motors. Unstring blocks, prepare tp separate pits. 4/29/2001 06:00 - 12:00 6.00 01 B RDMO Unstring drilling line. rig down pits. Blow down water and steam lines. Drain and clean #1 boiler. Prepare suction pit to move. Drain anti-freeze and change oil in #3 Cat. 398. Split draw works from motors. 12:00 - 21:00 9.00 01 B RDMO Rig down shaker pit, haul off. Remove derrick board, remove blocks. Set derrick on truck. Suck out sand trap and trip tank with super sucker. Lay down Nlegs. Set derrick off floor. Shut down for the night. 4/30/2001 06:00 - 18:00 12.00 01 B RDMO Move pit steps and landings, SCR breezeway,SCR, upper and lower volume pit, upper and lower suction pit, fuel tank and suit cases. Prepare pump room for move. PJSM Work with Sandstrm crane, take doghouses, electric motor house, floor plates and rotary table from rig floor. Dismantle spreader beams trolley and trolley beams. Pressure wash down sub base. 5/1/2001 06:00 - 18:00 12.00 01 B RDMO Pulled pumps, pressure washed pump room houses and loaded out. Clean matting boards, pressure washed all sub-bases, load out matting boards. PJSM Split sub-bases and pressure wash, rig down derrick, load on trailers, work with crane, split motors and boiler houses. 5/2/.2001 06:00 - 18:00 12.00 01 B PRESSURE WASH LOWER SUB SECTIONS, CLEAN SUCTION PIT & LOAD OUT MATTING BOARDS. LOAD TRAILERS W/DRK SECTIONS. RIG DOWN CRANE BOOM & RIGGING. CLEAN OBM F/ FROGS & LOAD OUT. P/U YARD. 5/3/2001 06:00 - 18:00 12.00 01 B CLEAN EQUIP. FOR BARGING, LOAD ON TRAILERS.OFF LOAD 4 EMPTY TRAILERS F/RED DOG BARGE. BACK LOAD W/3 TRALERS TESCO, 2 W/DRK WIND WALLS,1 W/A LEGS, 1WI DRK SECTION. LOAD OUT READOUBT BARGE W/16 LOADS, 4 398'S, 2 BOILERS,1 SUBBASE SECT, 1 SCR,1 TRAC. MTR BLD,1 DOG HOUSE & 6 TRAILERS. 5/4/2001 06:00 - 18:00 12.00 01 B RDMO Clean rig parts, organize barge loads, load two barges, prepare for two more loads. ,5/5/2001 06:00 - 18:00 I 12.00 01 B RDMO Organize trailer loads for barges, clean mats, prepare to finish demobilizing Nabors 160. 5/6/2001 06:00 - 18:00 12.00 01 B RDMO Load out the Redoubt with 11 loads, Red Dog came in with empty trailers. 3 more loads left. One more on the Redoubt, 2 more on the Printed: 5/15/2001 3:23:51 PM FOREST OIL CORP. Page 7 of 7 Operations Summary Report Legal Well Name: West McArthur River Unit #7 Common Well Name: West McArthur River Unit #7 Spud Date: 12/29/2000 ~Event Name: ORIG COMPLETION Start: 12/13/2000 End: Contractor Name: NABORS ALASKA DRLG Rig Release: Group: Rig Name: NABORS DRILLING Rig Number: 160 Date From - To~ Hours/ Code l cSoUdbe~ Phase I Description of Operations 5/6/2001 106:00- 18:00 r 12.00"~ 01 I B RDMO Red Dog. 5/?/2001 06:00 - 18:00 12.00101 B RDMO Load out the Redoubt, and the Red Dog. 5/8/2001 06:00 - 18:00 12.00 01 B RDMO Clean off herculite around the well heads. Load out the Red Dog twice. Down to 4 people this morning. R. Wall, A Lunda, G. Mize, roustabout Rick Gray. All personnel will be gone by noon today the 8th of May, 2001. 5/9/2001 06:00 - 18:00 12.00 01 B RDMO Demobilization finished. The Rig 'Nabors 160', has been stacked out in the Peak yard in North Kenai. The Herculite that was under the rig will be incinerated by Raven by the end of May. I i Printed: 5/15/200'1 3:23:51 PM 2490000 2488000 2486000 2484000 C;) 0 © 0 0 '0 0 0 o4 ',4' r42 We McArthu Traces O' 1000' 2000' 1" = 1000 feet Directional Surve Data Measured Inclination Direction Vertical Latitude Departure Vertical Do-91e~r Depth Depth Section (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100f) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 93.00 0.25 208.00 93.00 0.18 S 0.10 W -0.20 0.27 183.00 0.30 196.00 183.00 0.58 S 0.25 W -0.60 0.08 271.00 1.00 227.00 270.99 1.32 S 0.88 W -1.57 0.86 318.00 1.20 268.00 317.98 1.62 S 1.67 W -2.32 1.69 407.00 1.30 259.00 406.96 1.85 S 3.59 W -3.76 0.25 497.00 1.50 285.00 496.94 1.74 S 5.73 W -5.09 0.73 588.00 1.40 297.00 587.91 0.92 S 7.87 W -5.90 0.35 677.00 0.50 142.00 676.90 0.74' S 8.60 W -6.24 2.10 791.06 1.44 109.11 790.94 1.60 S 6.95 W -5.79 0.92 880.08 2.22 16.57 879.93 0.31 S 5.40 W -3.80 3.03 969.45 3.91 16.16 969.17 4.28 N 4.06 W 0.53 1.89 1059.73 3.69 43.68 1059.26 9.34 N 1.19 W 6.22 2.02 1153.80 4.89 70.89 1153.08 12.84 N 4.68 E 12.73 2.47 1247.44 6.71 67.58 1246.23 16.24 N 13.51 E 21.11 1.98 1342.72 7.23 56.72 1340.81 21.6,5 N 23.66 E 31.89 1.49 1436.31 7.64 42.89 14:33.62 29.44 N :32.83 E 43.79 1.96 1531.55 10.23 32.73 1527.71 41.20 N 41.71 E 58.48 3.17 1625.52 12.04 37.54 1619.90 55.99 N 52.19 E 76.51 2.17 1718.99 14.01 41.23 1710.97 72.23 N 65.59 E 97.§6 2.28 1813.00 17.02 42.62 1801.54 90.92 N 82.41 E 122.70 3.23 1905.90 20.22 43.98 1889.57 112.48 N 102.77 E 152.34 3.47 1988.97 22.40 41.34 1966.96 134.70 N 123.19 E 182.51 2.87 2083.05 22.90 38.70 2053.78 162.44 N 146.48 E 218.72 1.21 2176.87 22.30 31.26 2140.42 191.91 N 167.13 E 254.48 :3.11 2270.94 22.62 40.05 2227.37 221.03 N 188.04 E 290.15 :3.59 2364.,58 29.93 41.60 2311.28 252.33 N 215.18 E 331.58 7.84 2459.86 32.61 40.06 2392.71 289.76 N 247.49 E 381.02 2.93 2553.45 36.31 38.01 2469.87 330.91 N 280.80 E 433.92 4.15 2648.69 40.92 36.14 2544.27 378.34 N 316.58 E 493.16 4.99 2742.66 43.14 35.60 2614.06 429.33 N 353.44 E 555.78 2.40 2836.13 46.58 37.73 2680.31 482.18 N 392.83 E 621.48 4.02 2924.05 50.37' 39.88 2738.59 533.44 N 434.10 E 687.22 4.69 3018.40 52.40 42.74 2797.47 588.78 N 482.77 E 760.92 3.19 3111.84 52.25 42.40 2854.58 643.24 N 532.81 E 834.86 0.33 3206.15 52.20 42.46 2912.3,5 698.27 N 583.10 E 909.40 0.08 3299.63 51.92 42.44 2969.83 752.66 N 632.86 E 983.11 0.30 3393.21 52.14 41.84 3027.40 807.36 N 682.36 E 1056.87 0.56 3483.83 52.44 42.10 3082.83 860.66 N 730.31 E 1128.56 0.40 357,5.62 52.25 41.08 3138.91 915.01 N 778.54 E 1201.23 0.91 I. II Job No.: AK-MW-t0077 Well No.: West McArthur River Unit #7A End of Well Report Page 35 II Measured Inclination Direction Depth (feet) (degrees) (degrees) 3668.60 51.53 38.89 3764.93 51.36 38.92 3859.10 51.37 39.07 3952.36 51.63 38.70 4045.82 51.33 38.80 4139.01 50.38 38.70 4233.71 50.30 39.49 4327.50 49.15 39.63 4421.06 49.45 39.17 4513.65 49.94 39.12 4608.86 50,05 38.32 4701.84 48.80 39.19 4796.68 48.57 40.45 4891.03 47,86 40.55 4987.47 48.12 40.41 5078.78 48.52 40.59 5172.26 48.62 40.35 5265.84 48.66 39.99 5353.84 49.44 39.82 5448.25 50.35 39.87 5541.23 50.62 39.85 5635.31 50.97 40.09 5729.39 50,46 39.68 5823.21 50.71 39.93 5917.28 49.23 40.55 6010.92 48.43 42.26 6106.20 48.20 42.85 6199,79 48.41 43.53 6300.68 46.98 43.26 6394.65 45.75 43.54 6457.11 45.45 43.73 6527.63 44,19 43.39 6620.82 46,39 42.93 6715.52 49.19 41.57 6809.31 49.83 37.77 6902.87 49.39 37.52 6995.32 50.30 37.86 7090.67 49.56 37.54 7183.65 48.77 37.30 7278:49 50.27 38.68 Directional Survey Data Vertical Latitude Departure Vertical Depth Section (feet) (feet) (feet) (feet) (deg/lOOf) 3196.30 971.06 N 825.55 E 1274.35 2,01 3256.34 1029.68 N 872.86'E 1349.61 0.18 3315.13 1086.85 N 919.15 E 1423.11 0,13 3373.19 1143.66 N 964.97 E 1496.03 0.42 3431,40 1200.69 N 1010.74 E 1569.07 0.34 3490.23 1257.04 N 1055,98 E 1641.27 1.03 3550.67 1313.62 N 1101.95 E 1714.11 0.64 3611.31 1368.79 N 1147.52 E 1785.62 1,23 3672.32 1423.59 N 1192.53 E 1856.51 0,50 3732.22 1478.36 N 1237.10 E 1927.06 0.53 3793.43 1535.26 N 1282.72 E 1999.91 0.65 3853.91 1590.33 N 1326.92 E 2070.45 1.52 3916.52 1645.05 N 1372.53 E 2141.66 1.03 3979.39 1698.54 N ' 1418.21E 2212.00 0.76 4043.93 1753.05 N 1464.73 E 2283.65 0.30 4104.65 1804.91 N 1509.03 E 2351.84 0.45 4166.51 1858.22 N 1554.52 E 2421.92 0.22 4228.34 1911.90 N 1599.83 E 2492.14 0.29 4286.01 1962.88 N 1642.47 E 2558.59 0.89 4346.83 2018,32 N 1688.74 E 2630.77 0.96 4406.00 2073.38 N 1734.71 E 2702.47 0.29 4465.47 2129.25 N 1781.54 E 2775.35 0.42 4525.04 2185.12 N 1828.23 E 2848.14 0.63 4584.60 2240.81 N 1874.64 E 2920.60 0.33 4645.11 2295.79 N 1921.16 E 2992.61 1.65 ~706.75 2348.66 N 1967.78 E 3063.10 1.62 4770.11 2401.07 N 2015.91E 3134.24 0.52 4832.36 2452,03 N 2063.74 E 3204.09 0.58 4900.26 2506.25 N 2115.00 E 3278.66 1.43 4965.10 2555.66 N 2161.73 E 3346.63 1.33 5008,81 2587.96 N 2192.52 E 3391.22 0.53 5058.83 2623.98 N 2226,78 E 3440,89 1.81 5124.39 2672.29 N 2272.07 E 3507.08 2.39 5188.00 2724.22 N 2319.21E 3577.21. 3.14 5248.92 2779.11N 2364.72 E 3648.48 3.15 5309.54 2835.54 N 2408.25 E 3719.59 0.51 5369.15 2891.45 N 2451.45 E 3790.11 1.02 5430,53 2949.18 N 2496.07 E 3862.92 0.82 5491.33 3005.05 N 2538,82 E 3933.10 0.87, 5552.90 3061.90 N 2~83.22 E 4005.11 1.93 Job No.: AK-MW-10077 Well No,: West McArthur River Unit #7A End of Well Report Page 36. ii II II ii Measured Inclination Direction Depth (feet) (degrees) (degrees) 7372.84 51.97 39.53 7466.28 51.19 38.99 7560.59 50.79 38.94 7654.07 50.00 38.94 7747.65 48.91 38.62 7838.27 48,67 38.07 7930.06 49.41 38.18 7972.77 49.44 38.19 8034.01 50.15 40.01 8128.19 50.71 40.86 8220.64 50.75 41.00 8313.36 50.79 4t.01 8406.29 50.71 40.89 8497.95 49.95 40.26 8589,51 49.46 38.79 8683.68 47.56 37.03 8776.94 47.02 36.92 8870.40 46.74 36.71 8963.59 46.83 37.38 9058.29 48.37 37.96 9151.98 48.41 37.92 9245.64 47.61 38,07 9338.09 47.50 37,84 9433.59 48,24 38.80 9526.57 48.72 40,16 9621.41 48.88 40.65 9715.76 47.88 41.46 9809.20 47.93 41.75 9834.00 48.20 41.51 9920.28 42.70 48.53 10009,29 42.58 53.98 10102.81 43.95 62.99 10195.37 45.54 70.01 10289.14 43.79 76.84 10383.62 43.16 83.57 10477.40 44.31 90.76 10570.92 45.31 96.97 10664.92 46.13 103.48 10759.10 47.97 107.66 10851.55 49.72 112.10 Directional Survey Data Vertical Latitude Departure Vertical Depth Section (feet) (feet) (feet) (feet) Dogleg (deg/lOOf) 5612.12 3118.89 N 2629.55 E 4078.50 1.93 5670.18 3175.57 N 2675.88 E 4151.66 0.95 5729.54 3232.55 N 2721.97 E 4224.88 0.43 5789.13 3288.57 N 2767.24 E 4296.84 0.84 5849.96 3344.00 N 2811.78 E 4367.87 1.20 5909.66 3397.47 N 2854.07 E 4435,95 0.53 5969.83 3452.00 N 2896.87 E 4505.15 0.81 5997.62 3477.50 N 2916.92 E 4537.54 0.07 6037.15 3513.79 N 2946.42 E 4584.27 2.55 6097.15 3569.04 N 2993.51 E 4656.86 0.91 6155.67 3623.11 N 3040.40 E 4728.43 0.12 6214.30 3677.32 N 3087.53 E 4800.25 0.05 6273.10 3731.67 N 3134.69 E 4872.22 0.14 6331.62 3785.25 N 3180.58 E 4942.76 0.99 6390.84 3839.11 N 3225.02 E 5012.55 1.33 6453.23 3894.75 N 3268.37 E 5082.95 2.45 6516.49 3949.49 N 3309.58 E 5151.27 0.59 6580.37 4004.11N 3350.46 E 5219.27 0.33 6644.18 4058.32 N 3391.38 E 5287.00 0.53 6708.03 4113.67 N 3434.12 E 5356.78 1.69 6770.24 4168.92 N 3477.19 E 5426.71 0.05 6832.90 4223.77 N 3520.04 E 5496.20 0.86 6895.30 4277.56 N 3562.00 E 5564.30 0.22 6959.36 4333.12 N 3605.92 E 5635.02 1.08 7020.99 4386.86 N 3650.19 E 5704.60 1.21 7083.45 4441.20 N 3696.44 E 5775.95 0.42 7146.12 4494.39 N 3742.76 E 5846.48 1.24 7208.75 4546.24 N 3788.80 E 5915.82 0.24 7225.33 4560.03 N 3801.06 E 5934.27 1.29 7285.87 4603.55 N 3844.35 E 5995.54 8.61 7351.37 4641.26 N 3891.34 E 6054.90 4.15 7419.54 4674.63 N 3945.89 E 6116.00 6.76 7485.32 4700.53 N 4005.59 E 6174.90 5.60 7552.05 4719.37 N 4068.67 E 6230.73 5.45 7620.65 4730.43 N 4132.65 E 6281.33 4,94 7688.45 4733.59 N 4197.32 E 6326.45 5.44 7754.82 4729.12 N 4263.02 E 6366.53 4.80 7820.48. 4717.16 N 4329.17 E 6401.28 5.03 7884,67 4698.63 N 4395.53 E 6431.25 3,79 7945,52 4674.93 N 4460.95 E 6456.71 4,08 Job No.: AK-MW-lO077 Well No.: West McArthur River Unit #7A End of Well Report Page 37 Directional Survey Data Measured Inclination Direction Vertical Depth Depth (feet) (degrees) (degrees) (feet) 10943.55 50.45 114.68 8004.56 11037.20 50.73 117.82 8064.02 11128.86 50.47 117.42 8122.20 11220.42 50.38 116.64 8180.53 11314.59 50.35 116.31 8240.59 11407.85 50.08 115.51 8300.27 11500.97 48.05 117.87 8361.28 11594.16 45.05 125.66 8425.42 11688.86 44.73 127.22 8492.51 11782.65 44.09 126.79 8559.51 11876.21 44.22 126.78 8626.64 11968.66 43.74 126.68 8693.16 12064.01 42.67 124.93 8762.66 12156.99 42.30 116.23 8831.29 12251.83 41.95 106.73 8901.70 12346.18 43.51 97.70 8971.07 12439.62 44.56 89.13 9038.31 12533.93 43.44 79.65 9106.23 12627.41 41.39 70.39 9175.31 12720.99 39.93 59.97 9246.38 12811.61 39.40 51.36 9316.19 12872.62 39.28 52.11 9363.37 12950.28 39.39 52.11 9423.44 13011.64 48.02 52.37 9467.75 13041.55 52.53 52.69 9486.87 13066.82 56.87 53.54 950t.46 13109.87 65.32 54.12 9522.26 13140.03 73.24 55.58 9532.92 13177.08 83.65 54.90 9540.33 13227.05 90.25 53.52 9542.99 13264.30 92.65 50.05 9542.04 13289.83 94.91 49.10 9540.36 13318.32 96.67 46.44 9537.49 13352.20 97.94 44.28 9533.18 13384.67 96.29 43.48 9529.16 13411.84 96.67 43.31 9526,09 13428.68 95.00 43.41 9524.38 13441.61 94,38 42.83 9523.32 13459.81 93.30 42.55 9522.10 13475.14 91.88 41.67 9521.41 Latitude Departure Vertical Dogleg Section (feet) (feet) (feet) (deg/lOOf) 4646.91 N 4525.70 E 6478.49 2.29 4614.91 N 4590.58 E 6497.36 2.60 4582.07 N 4653.34 E 6514.21 0.44 4550.00 N 4716.20 E 6531.70 0.67 4517.66 N 4781.12 E 6550.35 0.27 4486.34 N 4845.58 E 6569.46 0.72 4454.77 N 4908.43 E 6587.32 2.91 4419.32 N 4965.92 E 6598.72 6.86 4379.63 N 5019.69 E 6604.48 1.21 4340.12 N 5072.10 E 6609.49 0.76 4301.09 N 5124,29 E 6614.70 0.14 4262.70 N 5175.74 E 6619.91 0.52 4224.50 N 5228.67 E 6626.23 1.68 4192.60 N 5282.63 E 6637.96 6.33 4169.34 N 5341.67 E 6659.55 6.72 4155.90 N 5404.12 E 6690.74 6.70 4152.08 N 5468.83 E 6730.65 6.47 4158.42 N 5533.88 E 6778.41 7.08 4174.59 N 5594.67 E 6830.73 7.02 4200.03 N 5649.88 E 6886.31 7.42 4232.57 N 5697.56 E 6942.25 6.09 4256.52 N 5727.93 E 6980.30 0.80 4286.76 N 5766.78 E 7028.66 0.14 4312.69 N 5800.27 E 7070.25 14.06 4326.67 N 5818.52 E 7092.82 15.11 4339.05 N 5835.02 E 7113.01 17.39 4361.26 N 5865.42 E 7149.77 19.65 4377.48 N 5888.47 E 7177.18 26.66 4398,15 N 5918.25 E 7212.37 28.16 4427.31N 5958.70 E 7261.00 13.48 4450.34 N 5987.95 E 7297.61 11.34 4466.86 N 6007.34 E 7322.83 9.59 4485.91N 6028.33 E 7350.99 11.14 4509.52 N 6052.24 E 7384.51 7.36 4532.74 N 6074.57 E 7416.70 5.65 4552.36 N 6093.12 E 7443.68 1.49 4564.54 N 6104.62 E 7460.42 9.91 4573.94 N 6113.43 E 7473.30 6.58 4587.29 N 6125,74 E 7491.46 6.13 4598,65 N 6136.01E 7506.77 10.86 Job No.: AK-MW-10077 Well No.: West McArthur River Unit #7A End of Well Report Page 38 Directional Survey Data ~ ~_~ D--eparture Vert,ca-'---~ ~ Measured Depth (feet) Inclination (degrees) Direction (degrees) Depth Section (feet) (feet) (feet) (feet) (deg/100f) 13498.92 13515.52 13532.58 13546.77 13566.47 13583.28 13601.35 13640.75 13670.65 13703.25 13733.54 13770.90 13806.13 13859.68 13888.95 13951.52 13979.24 14011.79 14048.84 14082.28 14110.94 14139.89 14170.30 14203.09 ~4273.00 89.63 87.57 85.53 85.13 85.31 85.46 85.95 86.76 86.36 85.90 84.97 84.75 86.64 88.15 88.89 88.21 87.48 86.92 88.77 88.34 88.21 87.04 86.98 87.23 87.23 41.78 41.80 41.46 41.17 40.85 40.97 41.17 41.14 40.67 41.08 40.61 40.46 40.43 41.03 40.93 41.13 41.13 41.50 41.80 41.92 41.17 39.76 38.98 39.25 39.25 9521.10 4616.40 N 6151.83 E 7530.55 9.48 9521.50 4628.77 N 6162.89 E 7547.14 12.44 9522.53 4641.50 N 6174.20 E 7564.17 12.08 9523.69 4652.12 N 6183.54 E 7578.31 3.49 9525.33 4666.93 N 6196.42 E 7597.94 1.86 9526.68 4679.60 N 6207.40 E 7614.70 1.18 9528.03 4693.18 N 6219.23 E 7632.71 2.94 9530.54 4722.79 N 6245.11 E 7672.03 2.05 9532.33 4745.34 N 6264.65 E 7701.88 2.06 9534.53 4769.94 N 6285.94 E 7734.40 1.90 9536.94 4792.78 N 6305.68 E 7764.60 3.45 9540.29 4821.06 N 6329.87 E 7801.80 0.69 9542.93 4847.79 N 6352.66 E 7836.93 5.35 9545.37 4888.33 N 6387.56 E 7890.42 3.05 9546.12 4910.42 N 6406.75 E 7919.67 2.55 9547.70 4957.60 N 6447.81 E 7982.22 1.13 9548.75 4978.46 N 6466.04 E 8009.92 2.67 9550.34 5002.88 N 6487.50 E 8042.43 2.04 9551.73 5030.55 N 6512.10 E 8079.46 5.06 9552.58 5055.44 N 6534.41E 8112.88 1.34 9553.44 5076.89 N 6553.41 E 8141.53 2.66 9554.64 5098.89 N 6572.18 E 8170.45 6.32 9556.22 5122.37 N 6591.44 E 8200.80 2.57 9557.88 5147.78 N 6612.10 E 8233.52 1.11 9561.26 5201.85 N 6656.28 E 8303.30 0.01 End of Well Report Page 39 Job No.: AK-MW-10077 Well No.: West McArthur River Unit #7A February 23, 1100 Finish review of Forest 401 for W. Mc RU #7A..,(201-042)...proposed sidetrack of original 2001 well.., plugging presently underway...felt for plug this morning,., not there.., have to set another...pass file on to Cammy. March 14, 2001 1445 Look at Forest 403 for W MCRU #7A...(201-042)...(301-058)...proPosal is to change the profile and BHL due to drilling information...check regulations and talk to Bob.,.looks like they need to file a 401 and $100. . . pass on information to Forest secretary. March 20, 2001 0700 Process paperwork change for new BHL at W MCRU #7...(201-042)...originally had submitted a sundry~ but BHL change was 670' requiring a 401. March 29, 2001 1000 Found original file for W. McRU #7A...(201-042)...intended BHL was changed due to drilling information...originaily submitted a sundry...BHL changed by more than 500' laterally so a 401 was required...had passed on, but Cammy said this application should route with the original...neither Diana or ! could find the original flle...pass on for finalization. April 3, 2001 1545 Talk to rob Stinson...calted with regard to WMcRU#7A BOP test and liner size...plans have changed and they plan to run a 4-1/2" slotted liner due to the dog legs presently in the 6- 3/4" hole section ALASKA OIL AND GAS CONSERYA~ION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul White Drilling Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 Re; West McArthur River Unit #7A Forest Oil Corporation Permit No: 201-042 Sur Loc: 2395' FNL, 1337' FWL, Sec 16, T08N, R14W, SM Btmhole Loc. 2050' FSL, 2570' FEL Sec 10, T08N, R14W, SM Dear Mr. White: Enclosed is the approved application for permit to re&ill the above referenced Well. The permit to re&ill 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. ~ Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC25 035. Sufficient notice (approximately 24 hours) must' be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. NotiCe may be given by contacting the commission at 279-1433. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this J'>~ day of April, 2001 j jo/Enclosures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 'i STATE OF ALASKA 'I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: X Redrill: I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: x 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 163' KB feet West Mc. Arthur River Field 3. Address 310 K Street, Suite 700 6. Property Designation West McArthur River Pool Anchorage, Alaska 99501 ADL-359111 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2395' FNL, 1337' F-VVL, Sec 16, T08N, R14W, SM West Mc. Arthur River Unit At top of productive interval 8. Well number Number Statewide #RLB0001940 2010' FSL, 1660' FWL Sec 10, T08N, R14W, SM West McArthur River Unit #7A At total depth 9. Approximate spud date Amount $200,000 2050' FSL, 2570' FEL Sec 10, T08N, R14W, SM 22-Feb-01 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3620 feet 850 feet 4,175 14,554' MD / 9,583' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: n/a 9,850' Maximum hole angle: 88 Maximum surface 1,099 psigAt total depth (TVD) 3,200 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD 'I'VD (include stage data) 6 3/4" 5 1/2" 17# L-80 Hyd 521 1,808' 12,746' 9,272' 14,554' 9,583' 254 cuft "ECEIVED :"'"" '"' 19. To be completed for Redrill, Re-entry, and Deepen Operations. I\ ' ( /,.:. ) ...' Present well condition summary ~ ~'' ','. ,.. ~ " Total depth: measured 12,950 feet Plugs (measured) MAR '~ 6 true vertical 9,423 feet " Effective depth: measured 12,950 feet Junk (measured)Alaslca 0il & Gas Oo,~,. true vertical 9,423 feet ~chorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 120' 20" Driven 120' 120' Surface 1,987' 13 3/8" to Surface 1,987' 1,967' Intermediate 6,536' 9 5/8" 672 cuft 6,536' 5,064' Liner 6,625' 7 5/8" 194 cu ft 12,946' 9,420' Production Perforation depth: measured true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: Diverter Sketch: Drilling program: Drilling,.f~d program: Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby f;ertif~ that the foregoing is true and correct to the best of my knowledge: Signed:--'\"~~~'""'~ ~' Paul White Title: Drilling Manager Date: ~,~/~ / Commission Use Only Permit Number201-042 IAPl number 50- 133-20500-01IiI Approva, ~l,at,.. ,~-~j/~. ',....,,:,¢~¢1 '.,:, ~.~..¢,, ,~..'~;::" ":' ,i f .,?~ /~eJ' I See c°ver letter for other requirements Conditions of approval Samples required: [ ] Yes ~No Mud IogZr~li~i'~d: '[iCj ~'No Hydrogen sulfide measures ~ Yes [ ] NoI~irectional survey required ~Yes, [ ] No 151~i Required working pressure forBOPE [ ]2M; ['¢~; [ ]SM; [ ] 10M; [ ] Other: ¢/_~/~~/ OR IGI NAL SIGt\I E{E,~ ~-J' ~" by order of Approved by D T:~vlor Se;:_~.n')ourlt Commissioner the Commission Date: RECEIVED Form 10-401 Rev. 12-1-85 MAR i 6 Z001 Alaska Oil & Gas Cons. Commission Anchoraae Submit in triplicate West McArthur River Unit #7A 20" 129~, X-56 ~ Driven Conducto~ 9 5/8" 47#, L-80 BTC Intermediate Casing 12 1/4" Hole 120' MD - 120' 'I-VD Ill 1,987' MD - 1,967' TVD 6,536' MD - 5,064' TVD 7 5/8" 29.7# L-80 Liner set ~ 12, 950' MD 9,423' TVD 8 1/2" Hole KOP ~ 9,850' MD, 7,236' TVD Kick Off Plug 9,770' MD - 10,150' MD 5 1/2" 17# L-80 Liner set ~ 14,554' MD 9,583' TVD - 6 3/4" Hole Abandonmem Plug 12,980' MD - 13,580' MD 8' 1/2" hole 14,009' MD - 10,322' TVD RECEIVED MAR 1 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage gSO0 A gSO0 Mc,~ E AlaskaOit FORE / ,/ 'West MCArthur River Fieic Top.~ Hemlock Pip 03/1'2/01 o' 1000' 20( , ,' .... ~" = ~000 feet Alaska Cook Inlet West Mc WMR#7 WP05 7200 7400 7600 78O0 8000 8200 C} 8400 ._ 1= 8600 8800 90OO 9200 o 9400 II o 9600 o ~ ~ 98o0 ~g ~° ~ nllQuest' 2 O0 08 001 I Dri!!Quest I i 5900 6100 6300 6500 6700 6900 7100 7300 7500 7700 7900 8100 8300 8500 8700 8900 Scale: lcm = 200ft Vertical Section Section Azimuth: 39.852° (True North) I DrilIQuest' Alaska Cook Inlet West Mc WMR#7 WP05 575O 5650 5550 545O 5350 525O 5150 · -- 5050 O Z 4950 4850 4750 4650 455O 4450 1-.- II o~ 4350 ~ 4250 Scale: lcm = 100ft Eastings 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 5500 5600 5700 5800 5900 6000 6100 6200' 6300 6400 6500 6600 6700 6800 Scale: lcm = lOOft Eastings Reference is True North 575O 5650 5550 545O 535O 525O 515O 5O5O 4950 485O 475O 4650 455O 4450 4350 4250 RECEIVE D DrillQuest 2.00.08,001 MAR 1 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Sperry-Sun Drilling Services Proposal Report for WMR#TA Wp05 Alaska Measured Sub-Sea Vertical Local coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 12950.00 39.820 52.110 9260,07 9423.07 4286.76 N 5766.85 E 13000.00 49.531 48.699 9295.58 9458.58 4309.20 N 5793.84 E 13100.00 69.143 44.094 9346.35 9509.35 4368.47 N 5855.55 E 13194.12 87.689 40.787 9365.18 9528.18 4436.27 N 5917.43 E 13200,00 87.689 40,787 9365.41 9528.41 4440.72 N 5921.27 E 13300.00 87.689 40.787 9369.45 9532.45 4516.37 N 5986.54 E 13400.00 87.689 40.787 9373.48 9536.46 4592.02 N 6051.81 E 13500.00 87.689 40.787 9377.51 9540.51 4667.67 N 6117.08 E 13600.00 87,689 40,787 9381.54 9544.54 4743.33 N 6182.35 E 13700.00 87.689 40.787 9385.57 9548.57 4818.98 N 6247.62 E Global Coordinates Northings Eastings (ft) (ft) 2487241.76 N 193021.85 E 2487264.20 N 193048.84 E 2487323.47 N 1 93110.55 E 2487391.27 N 193172.43 E 2487395.72 N 193176.27 E 2487471.37 N 193241.54 E 2487547.02 N 193306.81 E 2487622.67 N 193372.08 E 2487698.33 N 193437.35 E 2487773.98 N 193502.62 E 13800.00 87,689 40,787 9389.60 9552.60 4694.63 N 6312.90 E 13900.00 87.689 40,787 9393.64 9556.64 4970.28 N 6378.17 E 14000.00 87.689 40,787 9397.67 9560.67 5045.94 N 6443.44 E 14100.00 87.689 40,787 9401.70 9564.70 5121.59 N 6508.71 E 14200.00 87.689 40,787 9405.73 9568.73 5197.24 N 6573.98 E 2487649.63 N 193567.90 E 2487925.28 N 193633.17 E 2488000.94 N 193698.44 E 2488076.59 N 193763.71 E 2488152.24 N 1 93828.98 E 14300.00 87.689 40.787 9409.76 9572.76 5272,90 N 6639.26 E 2468227.90 N 14400.00 87,689 40.787 9413.79 9576.79 5346.55 N 6704.53 E 2488303.55 N 1 4500.00 87.689 40.787 9417.83 9580.83 5424.20 N 6769.80 E 2488379.20 N 14553.93 87.689 40.787 9420,00 9583.00 5465.00 N 6805.00 E 2488420.00 N All data is in Feet unless otherwise stated.-Directions and coordinates are relative to Grid North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot. 193894,26 E 193959.53 E 194024.80 E 194060,00 E Grid Convergence at Sudace is -1.528°. Magnetic Convergence at Surface is -22.507° (01-Feb-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 41.380° (Grid). Based upon Minimum Curvature type calculations, at a Measured Depth of 14553.93ft., The Bottom Hole Displacement is 8727.79ft., in the Direction of 51.233° (Grid), Dogleg Rate (°/lOOft) 20.00 20.00 20.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section Cook Inlet West Mc Comment 7o28.71 7063.39 7148.66 7240.43 7246,31 7346.22 7446.13 7546.05 7645.96 7745.87 7845.79 7945.70 8045.61 8145.53 8245.44 8345,35 8445.27 8545.18 8599.06 Target - T3, Current Target RECEIVED MAR 1 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage 12 March, 2001 - 11:31 Page 2 of 3 DrillQuest 2.00.08.001 Sperry-Sun Drilling Services Proposal Report for WMR#7A Wp05 Alaska Cook Inlet West Mc Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> 6600.00 5109.95 Casing Detail 9 5/8" Casing Targets associated with this wellpath Target Name T3 Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Easti ngs (ft) (ft) (ft) 9583,o0 9420.00 5465.00N 68O5.00 E 2488420.0o N 194O6O,0OE 6OO48'00.8224"N 208° 17'13.4560"E Target Target Shape Type Point Current Target RECEIVED MAR 1 6 Z001 Alaska Oil & Gas Cons. Commission Anchora9e 12 March, 2001 - 11:31 Page 3 of 3 DrillQues t 2. 00.08.001 R E .ST OIL C o R P O R A T I O N March 13,2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Attn: Re: Mr. Robert P. Cranda!l, Senior Petroleum Geologist Modification to Application for Spacing Exception West McArthur River Unit #7A Mr. Crandall, The path of West McArthur River Unit #7A has been modified, where it passes through the Hemlock formation. The well penetrated the Hemlock at 2010' FSL, 1660' FWL, Section 10, T8N, R14W, SM. This is 53 fl from the penetration submitted in 'the previous application for spacing exception. Attached is a plat map showing the new path through the Hemlock. Please notify us if Forest Oil will be required to amend or resubmit a spacing exception on this wellpath. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager- Alaska Division Forest Oil Corporation g~O0 ~/MRU Vl R U__~J A gSO0 McA, #2 IV FORE / // /West McArthur River Field Top Hemlock Plp '03/12/01 O' 1000' 200' , 1" - 1000 feet FOREST RATIO RECEIVED March 12, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 !~AR 1 g ~001 Alaska Oil & Gas Cons. Commission Anchorage Re' Application for Sundry Approvals West McArthur River Unit #7A N A sundry approval is requested to change the location of the 6 3A" production hole in the West McArthur River Unit #7A development well. Attached is the directional plan for the 6 3A" hole. The application for spacing exception as it pertains to this well will be amended with the new proposed bottomhole location. Logs from the 8 ½" hole indicated a need to adjust the wellpath to stay higher on the main WMRLI structure. The new path builds to a final inclination angle of 88 degrees, instead of the drop planned in the original applicalion. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager- Alaska Division Forest Oil Corporation Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission RE: West McArthur River Unit #7A Forest Oil Corporation, by letter dated February 22, 2001, has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of well that will be the second completion in a quarter section in the West McArthur River Unit, and will lie closer than 1,000' to an existing oil producer. The exception would allow Forest Oil Corporation to drill the West McArthur River Unit #7A well to a producing location of 1975' from the south line, 1620' from the west line, Section 10, TSN, R14W, Seward Meridian. A person may submit a written protest or written comments on the requested exemption prior to 4:00 PMon March 30, 2001 to the Alaska Oil and Gas Conservation Commission, 333 West 7Th Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing for 9:30 AM, March 30, 2001 at the Alaska Oil and Gas Conservation Commission, 333 West 7Th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission prior to 4:00 PM on March 15, 2001. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the tentative hearing, please call 793-1221. If you are a person with a disability who may need a special.modification in order to comment or to attend the public hearing, please contact Diana Fleck at 793-1221 before March 22, 2001. C~Ta~;lor~~ Commissioner Published February 28, 2001 ADN AO #02114012 FORCENERGY INC. - ANCHORAGE, AK 99501DATE ~'[arch 15, 2001 89-6/1252 ORDER OF WWl00 · 00WW~ · * ~e h~~ ~d 00/100'**** . DOLLARS a~ ~KA OIL AND GAS CONSERYA~ION COMMISSION Paul White, Drilling Manager Forest Oil Corporation 310 K Street, Suite 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 West McArthur River Unit No. 7 A Forest Oil Corporation Permit No: 201-042 Sur. Loc. 2395'FNL, 1337'FWL, Sec. 16, T08N, R14W, SM Btmhole Loc. 2370'FSL, 2130' FWL, Sec. 10, T08N, R14W, SM Dear Mr. White: Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Forest Oil Corporation will assume the liability of any protest to the spacing exception that may occur. Annular disposal of drilling wastes from this drilling operation have not been approved. If a Class II disposal well becomes unavailable, and a request for annular disposal is necessary, a complete request must be submitted with an Application for Sundry Approval (Form 10-403) and all necessary information required by 20 AAC 25.080. 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. The blOwout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test must be given so that a representative of the Commission may witness the tests if desired. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · ~ /tgffniel T. Seamount Commissioner BY ORDER OF TIlE COMMISSION DATED this ~_~c~ ~ day of February, 2001 dlffEnclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA O i_ AND GAS CONSERVATION ,..OMMISSlON PERMIT TO DRILL 2O AAC 25,005 la. Type of work Drill: X Redrill: I lb. Type of well E;ploratory~' .... Stratigraphic Test: Development Oil: x 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 163' KB feet West McArthur River Field 3. Address 310 K Street, Suite 700 6. Property Designation West Mc. Arthur River Pool Anchorage, Alaska 99501 ADL-359111 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2395' FNL, 1337' FWL, Sec 16, T08N, R14W, SM West McArthur River Unit At top of productive interval 8. Well number Number Statewide #RLB0001940 1975' FSL, 1620' FVVL Sec 10, T08N, R14W, SM West Mc, Arthur River Unit #7A At total depth 9. Approximate spud date Amount $200,000 2370' FSL, 2130' RNL Sec 10, T08N, R14W, SM 22-Feb-01 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3660 feet 850 feet 4,175 13,820' MD / 10,103' TVD 16. To be completed f¢r deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) ~'/~.5~ ' Kickoff depth:.,~-"'.l~ feet Maximum hole angle: 49 Maximum surface 1,178 psig At total depth (TVD) 3,200 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) 8 1/2" 7 518" 29.7# L-80 Hyd 521 6,542' 6,336' 4,925' 12,878' 9,303' 173 cu ft 6 3/4" 5 1/2" 17# L-80 Hyd 521 1,142' 12,678' 9,219' 13,820' 10,103' 180 cuft 19. To be completed for Redrill, Re-entry, and Deepen Operations. R E C E !~/E D Present well condition summary Totaldepth: measured 14,009 feet Plugs(measured) FEB 2, 2 Z001 true vertical 10,322 feet Effective depth: measured feet Junk (measured) Alaska 0il & Gas Cons. Commission true vertical feet Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 120' 20" Driven 120' 120' Surface 1,987' 13 3/8" to Surface 1,987' 1,967' Intermediate 6,536' 9 5/8" 672 cuft 6,536' 5,064' Production Liner Perforation depth: measured true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: Drilling program: X Drilling~,~ program: X Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: X 21. I herby ~s true and correct to the best of my knowledge: Signed: "~L/~~__~--,~' Paul White Title: Drilling Manager Date: , ~ ~ ) Commission Use Only Permit Number I APl number } Approval date I See cover letter 2.0 t 50- / - for other requirements ., Conditions of approval Samples required: [ ] Yes ~ No Mud log required: [ ] Yes [;~ No Hydrogen sulfide measures [ ] Yes ~ No Directional survey required [~] Yes [ ] No Required working pressure for BOPE []2M; ~[ ]5M; []10M; []15M L,\~1~O9¢,, Other: by order of Approved by Commissioner the Commission Date: Form 10-401 Rev. 12-1-85 Submit in triplicate Attachments o 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Outline Procedure Well Plan schematic Unit Maps Drilling Fluids Program Pressure Information Casing Design Cement Calculations Drilling Hazards - ~,xv_~v~ Directional Information Wellhead Schematic Nabors BOP schematic Nabors BOP equipment list Nabors Drilling Fluid System Description RECEIVED FEB 2 2 2001 Alaska Oil & Gas Cons, Commission Anchorage WEST MCARTHUR RIVER UNIT #7A OUTLINE PROCEDURE 1. RIH with 8 1/2" kick off assmebly. 2. Directionally drill 8 ½" hole to 12,878' MD / 9,303' TVD. 3. Run intermediate log suite. 4. Condition hole, Run and cement 7 5/8' liner from 6,336' MD to 12,878' MD. 5. Test 13 5/8" 5M BOP stack and equipment to 3,000 psi. 6. Pick up tapered drill string / BHA and run in hole. 7. Clean out liner and test lap to 3000 psi. 8. Clean out shoe track, drill 20' of new formation and Perform Formation Integrity 9. Test to 10.5 ppg EMW. 10. Directionally drill 6 3/4" hole to TD at 13,820'MD / 10,103' TVD. 11. Condition hole and run log suite as follows: Quad Combo and UBI (be prepared to run drill pipe conveyed logs) 12. Condition hole for liner. 13. Run and cement 5 ½" liner from 12,678' to 13,820'. 14. Clean out liner and test lap to 3000 psi. 15. Run Cement Bond logs, RST logs. 16. Run Tubing Conveyed Perforating guns and Production packer on drill pipe. 17. Pressure up drill pipe to set packer. POOH with drill pipe. 18. RIH and stab 2 7/8" completion into packer polished bore. 19. Nipple down BOPE and Nipple up .Production tree. 20. Swap well over to crude, fire guns with 2,500 psi to 2,800 psi and bring well online. RECEIVED FEB % ~ 2001 Alaska Oil & Gas Cons. Commission Anchorage West McArthur River Unit #7A 20" 129#, X-56 ~ Driven Conductor~l~ 17 1/2" Hole ~ 120' MD - 120' TVD ,987' MD - 1,967' TVD 9 5/8" 47#, L-80 BTC Intermediate Casing 12 1/4" Hole 7 5/8" 29.7# L-80 Liner set ~ 12,878' MD 9,303' TVD 8 1/2" Hole U 6,536' MD - 5,064' TVD KOP ~ 9,850' MD, 7,236' TVD Kick Off Plug 9,770' MD - 10,150' MD 5 1/2" 17# L-80 Liner set ~ 13,820' MD 10,103' TVD - 6 3/4" Hole Abandonment Plug 12,980' MD - 13,580' MD 8 1/2" hole 14,009' MD - 10,322' TVD RECEIVED FEB Alaska Oil & Gas Cons. Commission Anchorage West McArthur River Unit Unit Boundary Plat WMRU #7A T8N, R14W, Seward Meddian W. McArthur River Unit Forcenergy ADL 359111 ®#lA · #2A #7A 10 11 12 17 2O 15 14 WMRU Forcenergy ADL 359112 22 23 13 24 Forcenergy A-035017 29 28 27 26 25 32 Cook Inlet Bluff 34 36 1"= 1 mile IVER D- 1 MRU-6 'MRU-7P MRU RU-1A MRU-1 :ARTHUR RIV ST ivlcARTHUR RIVER EST FORELAN~_U~#2 ~2 'C '0' 1500' 3000' WEST MCARTHUR RIVER UNIT #7A DRILLING FLUID PROGRAM Interval Summary (8 112" hole) Well WMRU#7A Drilling Fluid System Mapco 200 Oil Base Mud- VersaDrill Oil Mud Key Products IMG 400 / M-I BAR / Mapco 200 / Vcrsacoat / Vcrsawet / VersaHRP / Versamod / Lime / CaCI2 / Ventrol 401 Solids Control Potential Problems Shale Shakers / Desander / Desilter / Centrifuge Coal sloughing, drill solids buildup, lost circulation Depth Mud Plastic Yield HTHP Interval Weight Viscosity Point Fluid Loss O/W Ratio Gels (ft) (PPG) (cP.) (LallOOft2) (ml/3Omin) (LB/lOOft2) 9500 - 12878' 9.0 - 9.2 20 - 25 20 - 25 < 6 cc's 80/20 15/30 · Current properties of oil mud in well (1200 bbls) · PPG 9.55; PV 29; YP 21; Solids 9%; Oil 76%; Water 14%; O/W Ratio 84/16; Lime 2.02; Chlorides 27% · Desired properties of oil mud (1200 bbls) · · PPG 9.0; PV 21; YP 21 +/-; Solids 8%; Oil 73%; Water 19%; O/W Ratio 80/20; Lime 1.25; Chlorides 25% · Condition oil base mud while kicking off cement plug. Reduce mud weight by running centrifuge continuously. · Maintain low shear rate values with IMG 400, Versamod, and VersaHRP. · Pump weighted high viscosity sweeps as needed to augment hole cleaning · If coal sloughing becomes a problem, consider increasing mud weight or spotting a 20 - 30 ppb Ventrol 401 pill across coal seams when tripping · Drill 8 1/2" hole to 12878'. Condition mud. Run and cement 7 5/8" liner. · Estimated total volume of fluid required- 470 bbls plus 1200 bbls of existing oil mud. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS Interval Summary (6 3/4" hole) Well MRU#7A Drilling Fluid System Key Products Solids Control Potential Problems Mapco 200 Oil Base Mud- VersaDrill Oil Mud IMG 400 / M-I BAR / Mapco 200 / Versacoat / Versawet / VersaHRP / Versamod / Lime / CaCI2 / Ventrol 401 Shale Shakers / Desander / Desilter / Centrifuge Coal sloughing, hole cleaning, lost circulation Depth Mud Plastic Yield HTHP Interval Weight Viscosity Point Fluid Loss O/W Ratio Gels (ft) (PPG) (cp.) (LBI100ft') (ml/30min) (LBI100ft2) 12878' - 13820 +/- 9.0 20 - 25 20 - 25 < 6 cc's 80/20 15/30 · Maintain low shear rate values with IMG 400, Versamod, and VersaHRP. · Keep mud weight as low as economically possible in this interval. NOTE: Formation pressure is estimated to be +/- 6.0 PPG. · Pump weighted high viscosity sweeps as needed to augment hole cleaning · If coal sloughing becomes a problem, consider increasing mud weight or spotting a 20 - 30 ppb Ventrol 401 pill across coal seams when tripping · Drill 6 3/4" hole to T.D. Condition mud. Run and cement 5 1/2" liner. · Displace well to crude oil after running liner. Use 1 - 2 drums of KleenUP i'or pit cleaning. · Estimated volume usage- 125 barrels new volume plus existing volume from 8 1/2" hole. · Centrifuge solids out of system prior to placing back in storage. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS WEST MCARTHUR RIVER UNIT #7A PRESSURE INFORMATION The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the West McArthur River Unit I/5. The pore pressure gradient information was obtained from the original bottom hole pressure surveys and RFT surveys on West McArthur River Unit #1,#2A and #3. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit # 1, #2A and #3. WMRU #2A, P= 4304 psi 9567' TVD from DST (as per 407 Comp Report, 11/93) WMRU #1, P= 4362 psi @ 9724' TVD from RFT (as per 407 Comp Report, 2/92) WMRU #3, P = 3680 psi @ 9400 from static BHP survey 7/2/95 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 any WMRU wells. 1) ASP = ((FG x .052) - 0.10) x D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.10 = gas gradient in psi/ft D = true vertical Depth of casing seat in ft RKB OR 2) ASP= FPP-( 1/3 x 0.10 x D) - (2/3 x .45 x D) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) ASP Calculations Drilling below Intermediate Casing (9 5/8") ASP OR = ((FG x .052)- 0.10) x D = ((10.5 x .052) -0.10) x 9303' = 4149psi r~cr~ ~,X,,xc~,~c~h~\c~-.,,-Z-C°~r}>/>.5 ASP - (9303' x .45) - (1/3 x .10 x 9303') - (2/3 x .45 x 9303') = 1085 psi Drilling below Drilling Liner (7-5/8") ASP OR = ((FG x .052)- 0.10) x D = ((10.5 x .052)- 0.10) x 10103' = 4506 psi ASP = (10103' x .45) - (1/3 x .10 x 10103') - (2/3 x .45 x 10103') = 1179 psi RECEIVED FEB g g ZOO1 Alaska Oil & (gas Cons. Gommission ^nchora§e Proposed Casing WEST MCARTHUR RIVER UNIT #7A CASING DESIGN Size Specifications Top Hole Casing Weight Grade Coupling Length MD 8 1/2" 7 5/8" 29 L-80 Hy 521 6542' 6336' 6 %" 5 %" 17 L-80 Hy 521 1142' 12678' Setting Depth Bottom TVD MD TVD 4925' 12878' 9303' 9219' 13820' 10103' Casing Joint Strength Body Strength Burst Collapse K lbs K lbs Psi Psi 7 5/8" 29// L-80 566 683 6890 4790 5 I/2" 17// L-80 338 397 7740 6290 Design Criteria Tension Burst Collapse Straight Hook Load - Ignoring Deviation and Buoyancy Full Column of Gas against deepest formation pressure Except for liners where a 3000 psi test pressure on top of 9.6 ppg fluid is backed on the outside by a fresh water gradient of 0.43 psi/ft. Full evacuation on the inside backed by expected formation gradient of 0.45 psi/ft on the outside. 7-5/8" 29.0#. Hydril 521 liner ~ 12,878' MD/9,303' TVD Tension = 6542' x 29.7# Rated = 566K = 194.3 K Safety Factor = 2.9 Burst = ((9303 x 0.4992) + 3000)- Rated = 6890 psi (9303 x 0.43) Safety Factor = 1.9 = 3644 psi Collapse = (9303 x 0.45)-(0.10 x 9303) Rated = 4790 psi = 3256 psi Safety Factor = 1.5 5-1/2"17//L-80 Hydril 521 liner ~.. 13,820' MD/10,103' TVD Tension = 1142' x 17// Rated = 338 K = 19.4 K Safety Factor = 17.4 Burst = ((10103 x 0.4992) + 3000)- Rated = 7740 psi (10103 x 0.43) Safety Factor - 2.1 = 3699 psi Collapse = (10103 x 0.45)-(0.10 x 10103) Rated = 6290 psi -- 3536 psi Safety Factor = 1.8 RECEIVED FEB 2001 Alaska Oil & Gas Cons. Commission Anchorage WEST MCARTmJR RIVER UNIT #7A CEMENTING PROGRAM Operator Name: Forest Oil Corpor~'-q Well Name: WMR #7t~ Job Description: WMR #7 7 5/8" Ddlling Liner Date: February 21,2001 Proposal No: 179651351D WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) DEPTH(fi) MEASURED I TRUE VERTICAL 8.681 CASING 8.500 HOLE 6,600 I 5,117 12,878 I 9,303 SUSPENDED PIPES DIAMETER (in) O.D. I I.D. I WEIGHT (lbs/fi) 7.625 6.875 129.71 DEPTH(fi) MEASURED I TRUE VERTICAL 12,878 I 9,3O3 Drill Pipe 5.5 (in) OD, 4.276 (in) ID, 19.5 (lbs/fi) set @ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 6,336 ff 6,336 ff 12,798 ff 9.20 ppg Oil Based 152 o F 130 ° F .... ~ .:::...~ VOLUME GALCULATIONS 1,50Off x 0.0770 cf/ft 80 ft x 0.2578 cf/ft with 32 % excess = with 0 % excess = TOTAL SLURRY VOLUME = ... 152 cf 21 cf (inside pipe) 173 cf 31 bbls Gr4117 Repo. Printed on: February 21, 2001 3:06 PM Page 6 Operator Name: Forest Oil Corporal," Well Name: WMR #7 Job Description: WMR #7 7 5/8" Drilling Liner Date: February 21,2001 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Liner Size/Weight: Pump Via Total Mix Water Required Pre-flush Water + 2 gpb MCS-AG Density Weighted Spacer MCS-4D Density Cement Slurry Class G Cement Density Yield Displacement Mud Density Proposal No: 179651351D 9,303 ft 12,878 ft 8.5 in 7 5/8in, 29.7 Ibs/ft Drill Pipe 5 1/2" O.D. (4.276" .I.D) 19.5 # 739 gals 20 bbls 8.4 ppg 40 bbls 10.5 ppg 150 sacks 15.8 ppg 1.15 cf/sack 409 bbls 10.0 ppg Gr4109 Report Printed on: February 21,2001 3:06 PM Page 5 Operator Name: Forest Oil Corpora,t~"q Well Name: WMR #7 Job Description: WMR #7 7 5/8" Ddlling Liner Date: February 21,2001 Proposal No: 179651351D FLUID SPECIFICATIONS Pre-flush Weighted Spacer VOLUME VOLUME FLUID CU-FT FACTOR 40.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 30.2 Ibs/bbl Bentonite + 119 Ibs/bbl Barite, Bulk + 100% Fresh Water @ 10.5 ppg AMOUNT AND TYPE OF CEMENT Cement Slurry 173 / 1.15 Displacement CEMENT PROPERTIES =,~l~-sacks Class G Cement + 0.05% bwoc R-1 + 0.3% bwoc CD-32 + 0.6% bwoc FL-33 + 1 gals/100 sack FP-6L + 43.7% Fresh Water 409.2 bbls Mud @ 10 ppg SLURRY NO. 1 Slurry Weight (ppg) 15.80 Slurry Yield (cf/sack) 1.15 Amount of Mix Water (gps) 4.93 Amount of Mix Fluid (gps) 4.94 Estimated Pumping Time - 70 BC (HH:MM) 3:10 Estimated Pumping Time - 100 BC (HH:MM) 3:13 Free Water (mis) @ 180 o F @ 90 o angle 0.0 Free Water (mis) @ 180 o F @ 45 o angle 0.0 Fluid Loss (cc/30min) at 1000 psi and 130 o F 40.0 Slight additive adjustments should be expected to achieve the desired slurry properties, based on Pilot Test results .~o~ .,.~d on: ~,~a~ 2~, 2oo~ 3:o~ PM Page Operator Name: Forest Oil Corporate' - Well Name: WMR #7 Job Description: WMR #7 5 1/2" Production Liner Date: February 21,2001 Proposal No: 179651351D WELL DATA ANNULAR GEOMETRY ANNULAR I.D. I DEPTH(fi) (in) I MEASURED I TRUE VERTICAL 6.875 CASING I 12,878 I 9,303 6.750 HOLE I ~3,~20 I ~0,~03 SUSPENDED PIPES DIAMETER (in) I WEIGHTI DEPTH(fi) O.D. I I.D. (lbs/fi) MEASURED I TRUE VERTICAL 5.500 I 4.892 I ~7 I 13,s20 I 10,~03 Drill Pipe 5.0 (in) OD, 4.276 (in) ID, 19.5 (lbs/fi) set @ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 6,300 ft 12,678 ft 13,780 ft 9.00 ppg Oil Based 161 o F 134 o F VOLUME CALCULATIONS 200 ft x 0.2578 cf/ft 200 ft x 0.0928 cf/ft 942 ft x 0.0835 cf/ft 40 ft x 0.1305 cf/ft with 0 % excess = with 0 % excess = with 34 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 52 cf 19cf 105 cf 5 cf (inside pipe) 180 cf 32 bbls RECEIVED FEB 2 2 2001 Alaska 0il & Gas Cons. Commission Anchorage Gr4117 Repolt Pdnted on: February 21,2001 3:86 PM Page 11 Operator Name: Forest Oil CorporatjF~ Well Name: WMR #7~. Job Description: WMR #7 5 1/2" Production Liner Date: February 21,2001 Proposal No: 179651351D JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Liner Size/Weight: Pump Via Total Mix Water Required Pre-flush 2% KCL + 2 gpb MCS-A Density Weighted Spacer MCS-4D Density Cement Slurry Liner Slurry Density Yield Displacement Mud Density 10,103 ft 13,820 ft 6.75 in 5 1/2in, 17 Ibs/ft Drill Pipe 5" O.D. 19.5~ and 3 %" O.D:1~5;5 ~ 765 gals 20 bbls 8.4 ppg 50 bbls 10.5 ppg 155 sacks 15.8 ppg 1.16 cf/sack 179 bbls 9.0 ppg Gr4109 Report P~nted on: February 21,2001 3:06 PM Page 10 Operator Name: Forest Oil Corpora[i."'~ Well Name: WMR #7 Job Description: WMR #7 5 1/2" Production Liner Date: February 21,2001 Proposal No: 179651351D FLUID SPECIFICATIONS Pre-flush Weighted Spacer VOLUME VOLUME FLUID CU-FT FACTOR Cement Slurry 180 I 1.16 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) 50.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 9 Ibs/bbl Potassium Chlodde + 30.2 Ibs/bbl Bentonite + 119 Ibs/bbl Badte, Bulk @ 10.5 ppg AMOUNT AND TYPE OF CEMENT =~-15'5 sacks Class G Cement + 0.1% bwoc R-1 + 2% bwow Potassium Chloride + 0.5% bwoc CD- 32 + 1 gals/100 sack FP-6L + 0.15% bwoc Sodium Metasilicate + 0.9% bwoc BA-10A + 43.8% Fresh Water 179.5 bbls Mud @ 9 ppg SLURRY NO. 1 15.80 1.16 4.94 4.95 Slight additive adjustments should be expected to achieve the desired slurry properties, based on Pilot Test results Report Printed on: February 21, 2001 3:06 PM Page 12 WEST MCARTHUR RIVER UNIT #7A DIRECTIONAL PROGRAM sl:~i~j-SUrl,I Alaska 0.,~.-,.....v,=.. Cook Inlet A ~O~ ~ny WMR#TA Si ,rack WP04 DrillQuest Proposal Data for WMI~C7AWp04 Vertical Origin: Well Hon:,ontal Odgin ' Well Measurement Units: ff Nerth Reference: Grid North Grid North Convergence. -1 528~ Dogleg severity. Degrees per 1 O0 feet VerlJcal Sec~on Azimubh: 51.725° VerlJcal Section Descri¢on: Well VerlJcal Section Odgin: 0.(30 N,0.00 E Coordinate System: NAD27 Alaska State Planes, Zone 4= US Foot Measured Incl. Azim. Vertical Northings Eastings Verlical Dogleg Depth Depth ~ection Rate 9850.00 48.375 41357 7235.99 4568.93 N 3809.00 E 5820.41 9880.00 48.400 43.765 7255.91 4585.45 N 3824.17 E 5842.55 6.00 10290.97 4~522 119.430 7910.41 467029 I~, 4401 44 E 634~.29 600 12024.02 48.522 119.430 8727.11 4216.37 N 5206.03 E 6698.75 0.00 12786.88 39.975 52.674 9303.00 4225.00 N 5675.00 E 7072.26 6.00 13569.84 39.975 52.674 9903.00 4530 00 ~ 6075.00 E 7575.21 0.00 13666.45 36.127 53.249 9979.07 4565.87 N 6122.52 E 7634.73 4.00 13819.89 36 127 53.249 10103.00 4620.00 N 6195.00 E 7725.16 000 7500 - 8000 - 8500 - 9000 - 9500 - _ 10000 - 0 II o ._ ~ 10500 - End DIr, Start Sail ~ 48.622°: 10790. g?ftMD, 7910.41ft'rVD Begin DIr~ 6.00~1100fl Exit ~_, 6.00°lJOOft, 90.00 TF DIr ~_, 6.00=1100ft : l)860.00ft MD, 7236.89ft 'FVD : 9880.00ft MD, 7256.91ff TVD Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates RKB Elevation: Grid North Convergence: North Reference: Units: WMR#7 248295500 N. 187255.00 E 82955.00 N, 7255.00 E OO° 47' 05.2578" N, 151" 45' 00.8949" W 163.00ft above Mean Sea Level 163.00ft above Structure -1.528~ Grid North Feet : 12024.02ft MD, 8727.1tfl 'rVD End DIr, Start Sail ~ 39.975a: 12786.SBftMD, g303.00ffTVD 7 5/8" Casing 12787.00' MD 9303,09' TVD WMR7A Hkt T1 ~"~°x S903.00 TVD, 4530.00 N, 6075.00 E .............. - ...... .... Total Depth: ~9.8~MD,10~O~0~VD // 51/~' Liner I I 5000 5500 6000 Scale: linch = 500ff / 13819.89' MD ..' 10103.00' TVD tNMR7A TD T3 /' ~0103.00 T~D, 4620.00 N, S195.00 E I I 6500 7000 Vertical Section I I 7500 8000 Section Azimuth: 51.725° (Grid North) ~l~lal~J-ml..~[ Alaska ( West McI OriliQuest o.,~.-,.. ~e..~,ces Cook Inlet WMR#7A Sid t ack WP04 Proposal Data for WM~7A Sidetrack Wp04 Ve~ical Odgin ' Well Hodzon~l Origin ' Well M~surement Un~s · No~h Refer~ce · Grid No~h Grid No~h ~nvergence ' -1.528° D~I~ seved~ · D~r~ per 100 f~t Ve~ical S~fion ~imuth · 51.725° Ve~ical S~tion D~cdption: Well Ve~ical S~fion Odgin ' 0.00 N,0.00 E C~rdinate S~tem · NAD27 Alaska State Plan~, Zone 4, US F~t Measured Incl. ~im. Ve~ical Nothings Eastings Ve~ical Dogleg Depth Depth Section Rate 9850.00 48.375 41.357 7235.99 4568.93 N 3809.00 E 5820.41 9880.00 48.400 43.765 7255.91 4585.45 N 3824.17 E 5842.55 6.00 10790.97 48.522 119.430 7910.41 4670.29 N 4401.44 E 6348.29 6.00 12024.02 48.522 119.430 8727.11 4216.37 N 5206.03 E 6698.75 0.00 12786.88 39.975 52.674 9303.00 4225.00 N 5675.00 E 7072.26 6.00 13569.84 39.975 52.674 9903.00 4530.00 N 6075.00 E 7575.21 0.00 13666.45 36.127 53.249 9979.07 4565.87 N 6122.52 E 7634.73 4.00 13819.89 36.127 53.249 10103.00 4620.00 N 6195.00 E 7725.16 0.00 Single Well Target Data for WMR~7A Sidetrack WP04 M~surement Units · ft Coordinate Target Point ~D TVD Northings Eastings Nothings Eastings Target Name Ty~ ss ASP Y ASP X Shape W~7A Hkt T 1 Ent~ Point 9303.00 9140.00 2487180.00 N 192930.00 E 4225.00 N 5675.00 E Point WMR7A TD T3 Ent~ Point 10103.00 9940.00 2487575.00 N 193450.00 E 4620.00 N 6195.00 E Point WMR7A WF T2 Ent~ Point 9903.00 9740.00 2487485.00 N 193330.00 E 4530.00 N 6075.00 E Point Approved /~ ~ ~ ~ % ~ ~ ~o~o~.~'~ ~ 4400 .,~ 4000 o ~ 3600 - ., I I I I I I I 3800 4200 4600 5000 5400 5800 6200 S~le: linch = 400ff Fastinns Reference is Grid Nodh ~I~J'SUI~.I Alaska o.,-L,., semv,ces Cook Inlet A Hal~lJrton Gom~ny West Mc c~ IDrillQuest' WMR#7A Si etrack WP04 Proposal Data for WM R#7AWp04 Vertical Origin: Well Horizontal Origin: Well Measurement Units: North Reference: Grid North Grid North Convergence: -1.528° Dogleg severity: Degrees per 100 feet Vertical Section Azimuth: 51.725° Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 E Coordinate System: NAD27 Alaska State Planes, Zone 4, US Foot Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 9850.00 48.375 41,357 7235.99 4568.93 N 3809.00 E 5820.41 9880.00 48.400 43.765 7255.91 4585.45 N 3824.17 E 5842.55 6.00 10790.97 48,522 119.430 7910.41 4670.29 N 4401.44 E 6348.29 6.00 12024.02 48.522 119.430 8727.11 4216.37 N 5206.03 E 6698.75 0.00 12786.88 39.975 52,674 9303.00 4225.00 N 5675.00 E 7072.26 6.00 13569.84 39.975 52.674 9903.00 4530.00 N 6075.00 E 7575.21 0.00 13666.45 36.127 53,249 9979.07 4565.87 N 6122.52 E 7634,73 4.00 13819.89 36.127 53.249 10103.00 4620.00 N 6195.00 E 7725.16 0.00 7500 - 8000 - 8500 - 9000 9500 10000 II "~ 10500 - I 5000 5500 Scale: linch -500ff 6.00°ll00ft, 90.00TF < 98~O.00ft MD, 7235.99ft TVD Oir @ 6.00°ll00ft : 9880.00ft MD, 7255.91fl TVD End Dir, Start Sail @ 48.522°: 10790.97ftMO,7910.41ftTVD Current Well Properties Well: WMFU¢7 Horizontal Coordinates: Ref. Global Coordinates: 2482955.00 N, 187255.00 E Ref. Structure: 82955.00 N, 7255.00 E Ref. Geographical Coordinates: 60° 47' 05.2578" N, 151 ° 45' 00.6949" W RKB Elevation: 163.00ff above Mean Sea Level 163.00ft above Structure Gdd North Convergence: -1.528° North Reference: Gdd North Units: Feet Begin Dir @ 6.00°ll00ft : 1202.4.02ft MD, 8727. Jilt TVD ~.moo.oo ~).0~ Venereal!~ End Dir Start Sail @ 39 9 ~ 9303.09~"~V~ .____,,.____ , %. 5 1/2" Liner .. ." 13819.89' MD ./ 10103.00' TVD Wl~ R7A TD T3 .. 't0103.00 TVD, 4~20.00 N, 6195.00 E I I I I I 6000 6500 7000 7500 8000 Vertical Section Section Azimuth: 51.725° (Grid North) Alaska ~ Cool( Inlet ~ w~t Mr, i:).~.~ WMRftT~~~ ~ P.~AL REPORT 21 2001 Februa~, Surface Coordinates: 2482955.00 N, 187255.00 E (60° 47' 05.2578" N, 151° 45' 00.6949" HO Kelly Bushing: 163.00ft above Mean Sea Level DRILLIN(~ SERVICES A Halliburton Company Proposal Ref: pro28 Sperry-Sun Drilling Services Proposal Report for WMI~7A Wp04 Alaska Nleasured Depth (ft) Incl. Sub-Sea Depth (ft) 9850.00 48.375 41.357 7072.99 7235.99 9880.00 48.400 43.765. 7092.91 7255.91 9900.00 47.861 45.205 7106.26 7269.26 10000.00 45.456 52.767 7174.94 7337.94 10100.00 43.590 60.905 7246.30 7409.30 10200.00 42.337 69.519 7319.54 10300.00 41.755 78.441 7393.86 10400.00 41.873 87.444 7468.46 1 0500.00 42.684 96.286 7542.52 10600.00 44.150 104.756 7615.22 10700.00 46.205 112.709 7685.76 10790.97 48.522 119.430 7747.41 10800.00 48.522 119.430 7753.39 10900.00 48.522 119.430 7819.63 11000.00 48.522 119.430 7885.86 11100.00 48.522 119.430 7952.09 11200.00 48.522 119.430 8018.33 11300.00 48.522 119.430 8084.56 11400.00 48.522 119.430 8150.80 11500.00 48.522 119.430 8217.03 11600.00 48.522 119.430 8283.26 11700.00 48.522 119.430 8349.50 11800.00 48.522 119.430 8415.73 11900.00 48.522 119.430 8481.97 12000.00 48.522 119.430 8548.20 Vertical Local Coordinates Depth Northings Eastings Northin~gs (ft) (fi) (ft) 4568.93 N 3809.00 E 2~7~ 4585.45 N 38~.~ ~24.17 i .45 N 1% 2487598.81 N ~ _ 2487637.17 N 7482. N 4009.61 E 2487665.74 N ~a~7556.~ ~ ~1 N 4073.84 E 2487684.21 N ~.~ 47~.38 N 4139.86 $ 2487692.38 N ~~ 4735.15 N 4206.98 E 2487690.15 N ~87~[ ~ 4722.56 N 4274.39 E 2487677.56 N ~i~7848.76 4699.74 N 4341.43 E 2487654.74 N 7910.41 4670.29 N 4401.44 E 2487625.29 N Global Coordinates Eastings (ft) 191064.00 E 191079.17 E 191089.60 E 191144.33 E 191202.89 E 191264.61 E 191328.84 E 191394.86 E 191461.96 E 191529.39 E 191596.43 E 191656.44 E 7916.39 4666.97 N 4407.33 E 2487621.97 N 191662.33 7982.63 4630.16 N 4472.58 E 2487585.16 N 191727.58 8048.86 4593.34 N 4537.83 E 2487548.34 N 191792.83 8115.09 4556.53 N 4603.09 E 2487511.53 N 191858.09 8181.33 4519.72 N 4668.34 E 2487474.72 N 191923.34 8247.56 4482.90 N 4733.59 E 2487437.90 N 191988.59 8313.80 4446.09 N 4798.84 E 2487401.09 N 192053.84 8380.03 4409.28 N 4864.10 E 2487364.28 N 192119.10 8446.26 4372.46 N 4929.35 E 2487327.46 N 192184.35 8512.50 4335.65 N 4994.60 E 2487290.65 N 192249.60 8578.73 4298.84 N 5059.85 E 2487253.84 N 192314.85 8644.97 4262.02 N 5125.11 E 2487217.02 N 192380.11 8711.20 4225.21 N 5190.36 E 2487180.21 N 192445.36 Dog leg Rate (°/lOOft) 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 5820.41 5842.55 5857.32 5929.85 5999.58 6065.74 6127.60 6184.49 6235.79 6280.92 6319.41 6348.29 6350.85 6379.27 6407.70 6436.12 6464.54 6492.97 6521.39 6549.81 6578.23 6606.66 6635.08 6663,50 6691.92 Cook Inlet West Mc Comment ST Exit @ 6.00°/100ft, 90.00 TF : 9850.00ft MD, 7235.99ff TVD Begin Dir @ 6.00°/100ft : 9880.00ft MD, 7255.91ft TVD End Dir, Start Sail @ 48.522°: 10790.97ftMD,7910.41ftT VD 21 February, 2001 - 11:21 Page 2 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Proposal Report for WMRII7A Wp04 Alaska Measured Depth Incl. Sub-Sea Depth (ft) 12024.02 48.522 119.430 8564.11 12100.00 46.053 114.213 8615.66 12200.00 43.202 106.691 8686.87 12300.00 40.895 98.415 8761.19 12400.00 39.232 89.451 8837.78 12500.00 38.299 79.978 8915.82 12600.00 38.152 70.277 8994.45 12700.00 38.798 60.682 9072.81 12786.88 39.975 52.674 9140.00 12787.00 39.975 52.674 9140.09 12800.00 39.975 52.674 9150.05 12900.00 39.975 52.674 9226.69 13000.00 39.975 52.674 9303.32 13100.00 39.975 52.674 9379.95 13200.00 39.975 52.674 9456.58 13300.00 39.975 52.674 9533.22 13400.00 39.975 52.674 9609.85 13500.00 39.975 52.674 9686.48 13569.84 39.975 52.674 9740.00 13570.00 39.969 52.675 9740.12 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft)~_~ (ft) 8727.11 4216.37 N 5206.03 E 2_~7~ 8778.66 4191.15 N 525_,~79 i 8849.87 4166.53 N L:~I~I~ 8924.19 4151.90 NO176~ . 9000.78 4147.4~j~ 9078.82 ~_~~_ --5512.96 E 9157.45 ~_~168.~ ~ 5672.60 E 2487123194 N 9235~~ N 5629.04 E 2487149.73 N 192461.03 E 192510.79 E 192576.47 E 192641.70 E 192705.76 E 192767.96 E 192827.60 E 192884.04 E 192930.00 E 9303.09 4225.05 N 5675.06 E 2487180.05 N 192930.06 E 9313.05 4230.11 N 5681.70 E 2487185.11 N 192936.70 E 9389.69 4269.07 N 5732.79 E 2487224.07 N 192987.79 E 9466.32 4308.02 N 5783.88 E 2487263.02 N 193038.88 E 9542.95 4346.98 N 5834.97 E 2487301.98 N 193089.97 E 9619.58 4385.93 N 5886.06 E 2487340.93 N 193141.06 E 9696.22 4424.88 N 5937.14 E 2487379.88 N 193192.14 E 9772.85 4463.84 N 5988.23 E 2487418.84 N 193243.23 E 9849.48 4502.79 N 6039.32 E 2487457.79 N 193294.32 E 9903.00 4530.00 N 6075.00 E 2487485.00 N 193330.00 E 9903.12 4530.06 N 6075.08E 2487485.06 N 193330.08 E Dog leg Rate (°/100ft) 0.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 Vertical Section 6698.75 6722.20 6758.51 6800.65 6848.16 6900.52 6957.15 7017.43 7072.26 7072.34 7080.69 7144.92 7209.16 7273.40 7337.63 7401.87 7466.11 7530.34 7575.21 7575.31 Cook Inlet West Mc Comment Begin Dir @ 6.00°/100ff : 12024.02ft MD, 8727.11 ft TVD End Dir, Start Sail @ 39.975°: 12786.88fflVI D, 9303. OOftT VD Target - WMR7A Hkt T1, Drillers Target 7 5~8" Casing Hemlock Begin Dir @ 4.00°/100ff : 13569.84ft MD, 9903.00ft -I-VD Target - WMR7A WF T2, Ddllers Target West Foreland 21 February, 2001 - 11:21 Page 3 of 6 DrillOuest 2.00.06 Sperry-Sun Drilling Services Proposal Report for WMR#7A Wp04 Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 13600.00 38.773 52.843 9763.31 13666.45 36.127 53.249 9816.07 Vertical Depth (ft) 9926.31 9979.07 10006.16 10086.93 10103.00 13700.00 36.127 53.249 9843.16 13800.00 36.127 53.249 9923.93 13819.89 36.127 53.249 9940.00 All data is in feet unless otherwise stated. Dire~[ii~s a~d (~ordinates are relative to Grid North. Vertical depths are relative to Well. Northings ~d Eastings are relative to Well. Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot. Local Coordinates Global Coordinates Northings Eastings Northin~s Eastings (ft) (ft) (ft)~ (ft) 4541.58 N 6090.23 E~2487~ 193345.23 E 4565.87 N 6122.52 E 193377.52 E 4577.71 N 2487532.71 N 193393.36 E 4612.98~P~ ~, 611.60 E~ 2487567.98 N 193440.60 E ~1~~ ~115.00 E-- -- 2487575.00 N 193450.00 E Gdd Convergence at Surface is -1.528°. Magnetic Convergence at Surface is -22.497° (19-Feb-01) The Dogleg Sevedty is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 51.725° (Gdd). Based upon Minimum Curvature type calculations, at a Measured Depth of 13819.89ft., The Bottom Hole Displacement is 7728.03ft., in the Direction of 53.286° (Gdd). Dogleg Rate (°/100ft) 4.00 4.00 0.00 0.00 0.00 Vertical Section 7594.34 7634.73 7654.50 7713.44 7725.16 Cook Inlet West Mc Comment End Dir, Start Sail @ 36.127°: 13666.45ftMD,9979.07ftT VD Total Depth: 13819.89ftM D, 10103.00ft TVD 5 I/Z' Liner Target - WMR7A TD T3, Drillers Target 21 February, 2001 - 11:21 Page 4 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Proposal Report for WMR#7A Wp04 Alaska Cook Inlet West Mc Comments Measured Depth (ft) 9850.00 9880.00 10790.97 12024.02 12786.88 13569.84 13666.45 13819.89 Formation Tops Station TVD (fi) 7235.99 7255.91 7910.41 8727.11 9303.00 9903.00 9979.07 10103.00 Measured Vertical Sub-Sea Depth Depth Depth (fi) (~) (ft) 12787.00 9303.09 9140.09 13570.00 9903.12 9740.12 Coordinates Northings (fi) 4568.93 N 4585.45 N 4670.29 N 4216.37 N 4225.00 N 4530.00 N 4565.87 N 4620.00 N Eastings Comment fit) ~, 3809.00 E ST Exit @ 6. TF · 9850.00ft MD, 7235.99fl: TVD 3824.17 E Begin MD, 7255.91ft TVD 4401.44 E End · 10790.97f'tMD,791Q41ftTVD 5206.03 E lO0ft · 12024.02ft MD, 8727.11ffTVD 5675.00 E Sail @ 39.975" · 12786.88fl:MD,9303.00ftTVD _ 607~ Dir @ 4.00°/10Oft · 13569.84ft MD, 9903.00ft TVD I~ Dir, Start Sail @ 36.127°: 13666.45ftlV1D,9979.07ftTVD T6tal Depth: 13819.89ftMD,10103.00ftTVD Northings (ft) 4225.05 N 4530.06 N Eastings Dip Dip Dir. Formation Name Deg. Deg. 5675.06 E 0.000 0.000 Hemlock 6075.08 E 0.000 0.000 West Foreland 21 February, 2001 - 11:21 Page 5 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Proposal Report for WMI~7A Wp04 Alaska Cook Inlet West Mc Casing details From To IVleasured Vertical Measured Vertical Depth Depth Depth Depth (ft) (fi) (f~) (ft) <Su¢ace> <Surface> 6600.00 5109.95 9850.00 7235.99 12787.00 9303.09 12787.00 9303.09 13819.89 Targets associated w~th this wellpath Target Name 9 5/8" Casing 7 5/8" Casing 10103.00 5 I/Z' LinE~ --~ ~ Target Entry TVD (it) Coordinates Northings Eastings Target (fi) (It) Shape WMR7A Hkt T1 WMR7A TD T3 WMR7A WF T2 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: 9303.00 4225.00 N 9140.00 2487180.00 N 60° 47' 48.3250" N 10103.00 4620.00 N 9940.00 2487575.00 N 60° 47' 52.3473" N 9903.00 4530.00 N 9740.00 2487485.00 N 60° 47' 51.4305" N 5675.00 E Point 192930.00 E 151 o 43' 08.6538" W 6195.00 E Point 193450.00 E 151 ° 42' 58.3875" W 6075.00 E Point 193330.00 E 151 ° 43' 00.7573" W Target Type Ddllers Target Ddllers Target Ddllers Target 21 February, 2001 - 11:21 Page 6 of 6 DrillQuest 2.00.06 Sperry-Sun Anticollision Report Company: Cook Inlet Date: 02/20/2001 Time: 17:13:25 Page: 1 Field: COOK INLET Reference Site: West McArthur River Unit Co-ordinate(NE) Reference: Well: West McAdhur River Unit #7 Reference Well: West McArthur River Unit #7 Vertical (TVD) Reference: Nabors 160 163.0 Reference Wellpath: West McArthur River Unit #7 A Db: Sybase GLOBAL SCAN APPLIED: Ail wellpaths within 200'+ 100/1000 of reference Reference: Plan: WMR#7AWIM & NOT PLANNED Pt Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9850.00 to 13819.89 ft Scan Method: Trav Cylinder North Maximum Radius: 1573.10 ft Error Surface: Ellipse+ Casing Casing Points MD TVD Diameter Hole Size Name. ft ~ ft in in 13893.99 10162.91 5.50 6.75 5 1/2" Plan: W MR#7AWp4 Date Composed: 02/20/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary <-~----'~--~--~ .... OffSetWellpath ---~---~-~--'-~--->. · Reference :Offset'. Ctr~Ctr No-Go AlloWable : · :' · . Site .... i i i ..~ · .~' "..' ' ' · Well... · · ~ '. ~ ~.' · i......WellPath. ' · : 'MD' '~ ...'" MD ~ .' Distance Area. .' · De~viation. · '..Warning. .' . : ".: . : . ' ' ..i. . .... :':': ii ' :." ' '.: 'ffi.'. '.: .ftil. i: :' ft: 'ii.::ff"" ' '.ft:: '. .... : .... West McArthur River West West McArthur River West West McArthur River West West McArthur River West West McArthur River West West McArthur River West West McArthur River West West McArthur River West West McArthur River West McArthur River WMR#1 Vl 12759.38 12000.00 1278.72 502.49 928.38 Pass: Major Risk McArthur River WMR#1AV0 12218.04 11200.00 1263.38 353.99 926.98 Pass: Major Risk McArthur River WMR #2A V1 13362.68 13100.00 701.80 495.19 231.17 Pass: Major Risk McArthur River WMR#3 V1 10272.63 10000.00 1509.65 406.31 1162.71 Pass: Major Risk McArthur River WMR#3ST V0 10272.63 10000.00 1509.65 406.27 1162.75 Pass: Major Risk McArthur River WMR #5 V1 11212.84 10900.00 767.31 315.08 490.35 Pass: Major Risk McArthur River Rig Surveys V2 10000.42 9900.00 1391.56 421.04 1103.83 Pass: Major Risk McArthur River WMR#6 WPs V2 Plan:Wt,~003.04 9900.00 1360.21 438.90 1058.91 Pass: Major Risk McArthur River WMR#7 Rig V0 9899.95 9900.00 1.48 0.52 0.97 Pass: No Errors )GRA --799 --750 --5O0 --250 --0 --250 --500 WELL DETAILS I ANTI-COLLISION SETTINGS +~-s +py-w ~al~g eas~g Lam& L,.gimdv,1 Sb~nterpolation' Method-MD Interval: 1 00.00 22.00 -21.0o 2482955.00 187255.0o 00:4T05.307N 151:45'00.690 l~,Depth Range From: 9850.00 To: 13g19.89 Maximum Range: 1573.10 Reference: Plan: WMRgTAWiM 0 W~t M~A, thur R;.-,-c,r U Cook Inlet Cakuhfion Method: Mi#inure Cunalure Elmr S2,~tem: ISCWSA Scan _Method: Troy Cyl~del Noah Enor Strface: EtUptieal + Cash~g 27O 24( --750 --799 50 180 [deg] vs Centre to Centre Separation [250fi/in] SURVEY PROGRAM Depth Fm DepthTo Sun-ey/Plan 9850.00 13819.89 Planned:WMRn7AWp4 VI Tool MWD From Colour To MD 0 6900 6900 7400 7400 7900 7900 8400 8400 8900 8900 9400 9400 9900 9900 10400 0400 10900 }00 11400 11900 90 ¸20 WELLPATII I)k-I-AII.S West McA~hm Riso Un~ #7 ^ Patent Wcl2palh: WMRn7 Rig Tie on MD: Io0off0o Rig: Ret IXitum-Nabo{~ Ifil) 163.0ofl V. Sectinn Ofigm ~ *~-S IF/-W Ftom~VD LEG~D ~ w~t Sk~hur Rk'et Uni ~1 (WMR al), Ma~r R~k ~ Wcsl Mc~m Rk~ Uni ffl (WMR ~IA), N~r R~ -- Wc~t g~hur R~ Unl -- Wot g~A~ur Rk~ Unl ffJ (WMR ~3). Mawr R~k -- West Mc~ Rh-o Uni U3 iWMR n3gT), Mawr R -- West ~ur Ri~ Uni ~ W~I Mc~ Rh-er Unl ~6 ( R~ Sun-~'s), Mawr Ri -- w~l XkMmm River Un~ ~6(WMR -- W~l Mc~m Rh'~ Unl ~7 IWMR~7 R~), No -- W~I Me.ur Rn~ Un~ a7 A ...... WMRiTAW~ Rn7AWp4 IWcst McAnhut R n-tn' Untl #7/Wcsl Mc,'~hut Rb,' Clcaled By: P¢~ch Ilnllzman Oatc: 02/20'20OI Ch~:kcd: Dale: SECTION DEq'AI LS Sec MDMc Afl TVD +N/-StFV-WDLcg'[FaceVSec Tatgcl 9850.0o 48 37 4136 7235.99 4569.46 38o9.24 0.000~0 5785.40 9880.00 48.40 43.767255.92 4585.98 3824.40 5.9889.845807.43 10790.97 48.52 119.43 7910.43 4670.85 44o1656.0O 117.15 6320.89 12024.02 48.52 119.43 8727.15 4216.94 52O6.23 0.0O o.0o 6~94.45 12786.88 39.97 52.679303.07 4225.57 5675.16 6.0o 215.46 7075 51 13569.84 39.97 52.679¢03.12 4530571~O75.O9 0.0o0.O07578.44 7 13666.45 36.13 53.25 9979.18 45fi6 44 6122.60 3.99 174.91 7637.98 8 13819.89 361353.25 10103.11 4620.58 6195O9O.C~} 00O 772845 West McArthur River Unit//7 A Well Head Schematic 13 5/8'3 N ~0' Casing 13 3/8' Casing Nabors Rig 160 13-5/8" 5000 psi BOP WMRU #7A Stack 5000 psi Annular 5000 psi Pipe Rams 5000 psi Blind Rams 3" Kill Line 1 = HCR Valve 2 = Gate Valve Mud Cross 5000 psi Pipe Rams 3" Choke Line 13-5/8"x 11" 11" 5M Wellhead 13-3/8" Surface Casing 9-5/8" Intermediate RECEIVED FEB g ~ ?~10t Alaska Oil & Gas (ions. (;ommissk)n Anchorage BLOWOUT PREVENTION EQUIPMENT NABORS RIG NO. 160 13-5/8" BOP Equipment 1 ea 13-5/8" x 5000 psi wp ram type preventers, double (Shaffer) 1 ea 13-5/8" x 5000 psi wp ram type preventers, single (Shafted 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, Valvcon, 300 psi w/12 bottles, 180 gallons, and (1) 80 gallon Valvcon accumulator. Accumulator pump, Gardner-Denver Triplex, Model PQ 172, air pump Model G7E. 8 bottles nitrogen backup. 1 ea Valvcon, 6 station, remote control panel 1 ea Thornhill Craver, automatic choke 3"- 10,000 psi with control choke panel 1 lot Hydraulic pipe and fittings from manifold to BOP stack. DRILLING FLUID SYSTEM DESCRIPTION Mud Pumps 2 ea Continental Emsco F-1300 triplex mud pumps 7" x 12, 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 GE traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum I with 50 HP AC motor. Mud Tank System (1035 bbls Total Volume) Tank #1 (shaker tank) appx. 270 bbls. Three compartments which include desander, desilter suction compartment and cutting trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desilter, mud cleaner, mud guns and mud agitators in top skidded section. Tank//3 (suction tank) appx. 305 bbls. Three compartments, two of which are pill pits, 1 thru 65 bbls; one 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Equipment 1 ea 1 ea 1 ea 1 ea 1 ea 4 ea 4 ea 1 ea 6 ea Derrick dual tandem shale shaker Swaco 518 high speed centrifuge Drilco degasser Pioneer 16 cone desilter Pioneer sidewinder mud mixer Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electric Motors Pioneer desander, 2 cone, Model S-2-12 Dahlory 3" mud guns FOR E ..ST OIL C o R P O RATION February 21, 2001 Alaska Oil and Gas Conservation Commission 333 West 7~ Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill (Form 10-401) West McArthur River Unit #7A Enclosed is the Application for Permit to Drill West McArthur River Unit #7A, in the West McArthur River Field. This well will be a re-drill, kicking off at 10,000' MD out of the plugged back West McArthur River Unit #7. This well is planned as a Hemlock producer in the primary WMRU fault block. We understand that a spacing exception will be necessary for this wellbore and will treat it as a separate issue. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager - Alaska Division Forest Oil Corporation RECEIVED FEB Alaska 0il & Gas Cons. Commission Anchorage FORCENERGY INC. PH. 907-258-8600 · 310 K STE. STE. 700 , ANCHORAGE. AK 99501 ~ J.--. , / _.. 89-6/1252 First National Bank ~~. ~ .... '~' /,' - ', "' -- ' ~ "' ' WELL PERMIT CHECKLIST COMPANY,~7~ ~)/"j/ ~VV_ ELL NAME .'~,,~ PROGRAM: exp day )~' redrll '~< serv == INIT CLASS _,~.j~ -/-'~'~7 GEOL AREA ~.2..~ UNIT# FIELD & POOL ADMINISTRATION 1. 8. ? 15. '15. 17. ~8. 'lO. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. GEOLOGY 30. 31. 32. 33. 34. wellbore sag ann. disposal para req ON/OFFSHORE Permit fee attached ....................... ~,5~N Lease number appropriate ................... ! I~ Unique well name and number .................. Well located in a defined pool .................. ~ N ' ' ' < - '- - /- .... Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... N ..... , - ' '.~ ' ~, ,~ - -/-; ' - Sufficient acreage available in drilling unit ............ ~~/~, If deviated, is wellbore plat included ............. . . N .~/ ' - Operator only affected party ................... E~,N N Operator h a s appropriate bond in force ............. -~~N., Permit can be issued without conservation order ........ Permit can.be issued without administrative approval ...... ~~j~ N ........... // Can permit be approved before 15-day wait ........... Conductor string provided ................... Y Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ..... . . . . Y N~ ........ ,,....~.~ ~, - - /~4~'~"~' ,~ ~-- - -~'/' ' ' .... ''/ '~-'~ CMT will cover all known productive horizons ..... ..... Y N //~,., Casing designs adequate for C, T, B & permafrost ....... Y N -- - Adequate tankage or reserve pit ................. Y N _~.._ If a re-drill, has a 10-403 for abandonment been approved... Y N '~:~ --~'./ Adequate wellbore separation proposed. . Y N If diverter required, does it meet regulations .......... Y N ' - ~ - ' ' Drilling .fluid program schematic & equip list adequate ..... Y N BOPEs, do they meet regulation ................ Y N BOPE press rating appropriate; test to psig. Y N [ ~"*',- .L~._. ~ ..'P-~, . _.,,. = - .._~,. ___t...~\ ' Choke manifold complies w/APl RP-53 (May 84) Y N - - ----~ -, --> -t- -,~,,~ -,,~ x ',,~c_~. ~ [,-..-, ~,,~,c~, Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. ~ N Permit can be issued w/o hydrogen sulfide measures ...... Y(/'~/ ' Data presented on potential overpressure zones . ...... Y~ . ~ ,./,~' Seismic analysis of shallow gas zones... .... . . . ~.. ,,,Y,/' N ,,,,'I..~/.~/ Seabed condition survey (if off-shore). ............ Contact name/phone for weekly progress reports [exploratory, j~ly] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ..... ... APPR DATE (B) will not contaminate freshwater; or cause ddlling waste... to surface; ' (C) will not impair mechanical integrity of the well used for diSposal; (D) will not damage producing formation or impair recovery from a pool; and (E) wi!I not circumvent 20 AAC 25.252 or 20 AAC 25.412~ Y N Y N GEOLOGY: Y N Y N Y N ENGINEERING:. UIC/Annular COMMISSION: TE~ ~j, g ' JMH [~j~ Comments/Instructions: 0 Z 0 c:Vnsoffice\wordian~diana\checklist (rev. 111011100) , WELL PERMIT CHECKLIST COMPANY ~/"[;. ~-~-~ WELL NAME .~/~,igLL 7/~ PROGRAM: exp FIELD & POOL ~ / ~ INIT C~SS ~ ~ /~/~ GEOL AREA ADMINIST~TION 1. Pe~it fee a~ached ....................... 2. Lease number appropriate ................... ~U 3. Unique well name and number .................. N 4. Well Io~ted in a defined pool .................. 5. Well Io~ted proper distance from ddlling unit bounda~ .... 6. Well Io~ted proper distance from other wells. ~ ....... 7. Sufficient acreage available' in drilling unit ............ Y~ 8. If deviated, is wellbore plat included. ~' N .............. ~ 9. Operator only affe~ed pa~ ....... ~ .......... ~ 10. Operator has appropriate bond in force ............. ~ N / / 11. Pe it beissued withoutconse ation order........ Y / II A~R~,) DATE 12. Can permit be approved before Pe~it ~n.be issued without administrative a~p~l ...... ~N '~'ENGINEERING 1~. Conductor stdng provided ................... Y 15. Sudace ~sing protects all known USDWs ........... ~4 ~ ~~r~ ~' ~,~ ~- 16. CMT vol adequate to circulate on conductor & su~ ~g ..... 17. CMT vol adequate to tie-in long string to su~ csg ........ Y N 18. CMT will ~ver all known productive horizons .......... ~ N 19. Casing designs adequate for C. T. B & permafrost ....... ~ N 20. Adequate tankage or rese~e pit ................. N 21. If a re-drill, has a 10~03 for abandonment been approved... N 22. Adequate wellbore separation proposed ....... : ...... N 23. If dive,er required, does it meet regulations 24. Drilling .fluid program schematic & equip list adequate ...... ~ N 25. BOPEs. do they meet regulation ................ ~ N ~~~R DATE 26. BOPE press rating appropriate; test to ~~ psig. . . ~[~% 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ ~ I ~ ~ ' 28. Work will occur without operation shutdown ........... ~ ' 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit ~n be issued wlo hydrogen sulfide measures ..... ~N 31. Data presented on potential ove~ressure zones ....... Y~ 32. Seismic analysis of shallow gas zones ............. .~ N APPR DATE 33. Seabed condition su~ey (if off-shore) ........... /~ Y N ,A~ Z.ZZ' ~( 34. Contact name/phone for weekly progress repods [exp~o~ only] Y N .... . ................ ANNULAR DISPOSAL35. With proper cementing records, this plan ................. . (A) will contain waste in a suitable receiving zonej ' Y N /.. APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recove~ from a Y N // pool; and / (E) will not circumvent 20 ~C 25.252 or 20 ~C 25.412. Y N / GEoLoGY: ENGINEERING: UIC/Annular COMMISSION: Commen~llnstructions: O Z O rtl Z -.-I c:~'nsoffice\wordian\diana\checklist (rev. 11/01fl00) FOREST OIL CORPORA TION WEST MCARTHUR RIVER UNIT #7 SIDETRACK #1 WEST MCARTHUR RIVER FIELD SECTION 16-TSN-R14W, SM UPPER COOK INLET, ALASKA FINAL WELL REPORT APRIL 4, 200f Lees F. Browne- Sr. Logging Geologist Lowell D. Price- Logging Geologist George Klemmick-. Logging Geologist Barry Wright- Logging Geologist Doug Ottke- Logging Geologist EPOCH TABLE OF CONTENTS FOREST OIL CORPORA TION WEST MCARTHUR RIVER UNIT #7 SIDETRACK #1 WEST MCARTHUR RIVER UPPER COOK INLET, ALASKA WELL RESUME .............................................................................................................. 3 LITHOLOGY AND COMMENTS ..................................................................................... 5 DALLY CHRONLOGY .................................................................................................... 19 SURVEY RECORD ....................................................................................................... 26 MUD RECORD .............................................................................................................. 28 BIT RECORD ................................................................................................................ 30 DALLY REPORTS ......................................................................................................... 32 FINAL LOGS ................................................................................................ APPENDIX 1 EPOCH FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 WELL RESUME Company: Forest Oil Corp. Well: West McArthur River Unit #7 Sidetrack #1 Field: West McArthur River Region: Location: Cook Inlet Section 16, Township 8N, Range 14W, SM Coordinates: 2395' FNL, 1337' FWL Elevation: 163' RBK, 134' GL County, State: Kenai, Alaska APl Index: Spud Date (Sidetrack): Total Depth: Contractor: 50-133-20500-00 2/25/2001 14,273'; (9561' TVD); 04/04/2001, 15:00 hrs Nabors Alaska Drilling Company Representative: Derry Thompson Mike Mello Rig/Type: Epoch Logging Unit: Epoch Personal: Company Geologist: Nabors #160/Land #14 Lees F. Brown Jr. George Klemmick Barry Wright Doug Ottke Fletcher England Art Saltmarsh [:1 EPOCH 3 Casing Data: Hole size: Mud Type: Logged Interval: Electric Logging Co: Logs Run: FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 20" landed at 120' 13 3/8" landed at 1,995' 9 5~8" landed at 6,535' 7 518" landed at 12,946' 5 5~8" production liner landed at 14,273' 17 %" to 1,995' 12 %" to 6,535' 8 %" to 12,946' 6 %" to 14,273' Spud to 1,995' LSND to 6,535' Oil Based to 14,273' Monitor Gas 140' to 1,995' Full Logging 1,995' to 14,273' Schlumberger 161' to 7,002': Caliper-Gamma Ray Array Induction-Density-Neutron-GR 14,004' to 6,990': Caliper-Gamma Ray Army Induction-Density-Neutron-GR 15,266' to 14,016': 15,240' to 14,016': Caliper-Gamma Ray Array Induction-Density-Neutron-GR Ultra Sonic Bore Hole Imager [::1 EPOCH 4 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 LITHOLOGY AND COMMENTS 9775' CEMENT CONTAMINATION = GRAYISH BROWN; FIRM TO STIFF; EARTHY TO SUBPLANAR FRAC; SUBTABULAR TO SUBBLOCKY HABIT; EARTHY LUSTER; SILTY TO SUCROSIC TO GRITTY TEXTURE; COFFEE GROUND APPEARANCE; MASSIVE SECTION; OCCASIONAL TRACE OF SAND, CLAY AND COAL FRAGMENTS; CONTINUED CEMENT CONTAMINATION AS THE BIT IS DIRECTED AWAY FROM THE OLD WELL. 9840' COAL = BLACK; FIRM OCCASIONALLY HARD IN PARTS; RESINOUS LUSTER; SMOOTH TO MATTE TEXTURE; DISTINCT SUBCONCH TO CONCH FRAC PREDOMINANTLY COMPOSED OF BITUMINOUS COAL; VISIBLE BLEEDING GAS IN CUTTINGS. 9855' SAND = VERY LIGHT GRAY TO LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE LOWER; SUBROUND; MODERATE SPHERICITY; MODERATE SORTING; IMPACTED TEXTURE; NON TO VERY WEAK SILIC CEMENT; NO VISIBLE MATRIX MATERIAL; DOMINANTLY GRAIN SUPPORT; COMPOSED OF 50% QUARTZ, 40% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; GOOD ESTIMATED POROSITY AND PERMEABILITY; OIL BASE MUD. 9905' SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM MEDIUM LOWER TO FINE LOWER; SBRD TO SUBANGULAR; MODERATE SPHERICITY; MODERATE SORTING; IMPACTED OCCASIONALLY CHIPPED TEXTURE; NON TO VERY WEAK SILIC CEMENT; NON TO SLIGHTLY VISIBLE MATRIX CLAY; DOMINANTLY GRAIN SUPPORT; COMP OF 50% QUARTZ, 40% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; GOOD POROSITY AND PERMEABILITY; NO OIL INDICATORS. 9955' TUFFACEOUS SlLTSTONE = LIGHT GRAY TO PINKISH GRAY; POOR iNDURATION; BRITTLE; CRUMBLY OCCASIONALLY CRUNCHY; SLIMY; EARTHY FRAC; SUBNODULAR HABIT; MODERATE EARTHY LUSTER ASHY-SILTY TEXTURE; THICK BEDS OF REWORK SILTS AND CLAYS; GENERALLY COMPOSED OF 50% SILT, 40% CLAY, 10% VFGR SAND, CARBONACEOUS AND OTHER DETRIAL MATERIAL. 10015' SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM MEDIUM LOWER TO FINE LOWER GRADING TO MEDIUM UPPER OCCASIONALLY COARSE LOWER WITH DEPTH; SUBROUND; MODERATE SPHERICITY; MODERATE SORTING; PREDOMINANTLY IMPACTED FRAGMENTS; NON TO VERY WEAK SILIC CEMENT; OCCASIONALLY CONS IN PARTS; NON TO VERY SLIGHT CLAY/SILT MATRIX; DOMINANTLY GRAIN SUPPORT; COMPOSED OF 50% QUARTZ, 40% CHERT, 10% METAMORPHIC, FELDSPAR AND VAR LITHIC EPOCH 5 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 FRAGMENTS; FAIR TO GOOD ESTIMATED POROSITY AND PERMEABILITY; NO OIL INDICATORS. 10075' TUFFACEOUS SlLTSTONE = LIGHT GRAY TO LT BROWNISH GRAY OCCASIONALLY PALE YELLOWISH BROWN; POOR TO MODERATE INDURATION; CRUMBLY; MUSHY OCCASIONALLY STIFF; VARIOUS CONSISTENCIES; EARTHY FRACTURE; SUBBLOCKY HABIT; EARTHY TO SILTY TEXTURE; THICK GRAD BEDS OF SILT, CLAY AND FINE SAND. 10115' COAL = BLACK; FIRM TO HARD; RESINOUS LUSTER; SMOOTH TEXTURE; BLOCKY TO SUB HACKLY FRACTURE; COMPOSED OF PREDOMINANTLY BITUMINOUS COAL; SLIGHT VISIBLE BLEEDING GAS IN CUTTINGS. 10160' TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM GRAY; FIRM; STIFF; EARTHY TO IREG FRACTURE; SUBTABULAR TO SUBBLOCK HABIT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; THICK BEDS OF GRAD SILTS AND CLAY; COMPOSED OF 50% CLAY, 40% SILT 10% VFGR SAND AND DETRITAL MATERIAL. 10200' COAL = BLACK TO BROWNISH GRAY; SOFT TO OCCASIONALLY HARD, RESINOUS TO SMOOTH LUSTER; BRITTLE; PLANAR TO LOCAL CONCOIDAL FRACTURE; PLATY TO TABULAR CUTTINGS HABIT; SMOOTH TEXTURE; INTERMIXED WITH VARIOUS AMOUNTS OF TUFFACEOUS SILTSTONE; CARBOACEOUS SHALE, AND ASHY CLAY. 10240' TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM BROWN; FIRM; STIFF; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO PLATY HABIT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE WITH COMM CARBONACEOUS SILT AND CLAY LAMINAE. 10275' COAL = BLACK; TOUGH AND HARD; BLOCKY TO CONCHOIDAL; TABULAR TO MASSIVE HABIT; VITREOUS TO RESINOUS LUSTER; VERY CLEAN COAL UNIT 10300' TUFFACEOUS SlLTSTONE = LIGHT TO MEDIUM BROWN GRAY; LUMPY TO MUSHY; CRUMBLY; BLOCKY FRACTURE; EARTHY LUSTER; FAINT CARBONACEOUS LAMINAE; COM COMPOSED OF 60% QUARTZ, 40% LITHICS, SOME COAL LITHICS; UNCONSOLIDATED. 10330' SAND/SANDSTONE = MEDIUM BROWN GRAY TO OLIVE GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO COARSE UPPER; POOR TO MODERATE SORTED; SUBROUND TO SUBANGULAR; MODERATE SPHERICITY; IMPACTED AND FROSTED TEXTURE; COMPOSED OF 50% CHERT, 40% QUARTZ, AND 10% LITHICS; DOMINANTLY GRAIN SUPPORTED WITH WEAK CALCAREOUS CEMENT; POOR TO FAIR ESTIMATED VISUAL POROSITY; COMMON CLAYST AND SILTSTONE; DIRTY SAND; OIL IND OBSCURED BY OIL-BASED MUD. [::1 EPOCH 6 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 10390' SAND = LIGHT TO MEDIUM GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO COARSE LOWER; FAIRLY SORTED; SUBROUND TO ROUNDED; MODERATE SPHERICITY; POLISHED TO FROSTED TEXTURE; PREDOMINANTLY UNCONSOLIDATED WITH WEAK CALCAREOUS CEMENT; COMPOSED OF 50% QUARTZ, 30% CHERT, AND 20% MIXED LITHICS; FAIR ESTIMATED VISUAL POROSITY; OIL INDICATORS OBSCURED BY OIL-BASED MUD. 10440' TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY TO MEDIUM GRAY; FIRM TO SLIGHTLY HARD; IRREGULAR FRACTURE; TABULAR TO BLOCKY CTGS; DULL TO EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; THICK BEDS OF UNIFORM CLAY; OCCASIONALLY CARBONACEOUS LAMINATIONS. 10475' TUFFACEOUS SlLTSTONE = BROWNISH GRAY; MODERATE INDURATION; STIFF; EARTHY FRAC; SUBBLOCKY HABIT; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; MASSIVE BEDS OF GRAD SILTS AND CLAYS; GENERALLY COMPOSED OF 70% SILT, 20% CLAY, 10% DETRITAL MAT; OCCASIONALLY VISIBLE PLANAR ORIENTATION; OCCASIONALLY VISIBLE PYROCLASTIC RELIC SHARDS. 10555' COAL = BLACK; FIRM OCCASIONALLY HARD IN PARTS; RESINOUS LUSTER; SMOOTH OCCASIONALLY MATTE TEXTURE; SUBTABULAR TO SUBPLATY; SUBCONCOIDAL TO CONCHOIDAL FRACTURE; COMPOSED OF PREDOMINANTLY BITUMINOUS COAL; OCCASIONALLY VISIBLE BLEEDING FROM CUTTINGS. 10565' TUFFACEOUS CLAYSTONE = PALE BROWN TO PALE YELLOWISH BROWN; VERY SOFT; BECOMING CLOTTED TO MUSHY; AMORPHOUS FRACTURE AND HABIT; EARTHY LUSTER; ASHY TEXTURE; MASSIVE BEDS OF VERY HYDROPHILIC CLAYS; OCCASIONALLY INTBD WITH VERY FINE TO FINE GRAINED SANDS 10600' SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM COARSE LOWER TO FINE UPPER; SBRD; MODERATE SPHERICITY; POOR SORTING; IMPACTED TO OCCASIONALLY POLISHED TEXTURE; NON TO VERY WEAK SILIC CEMENT; SLIGHT CLAY MATRIX; DOMINANTLY GRAIN SUPPORT W/MINOR SECONDARY MATRIX SUPPORT; COMPOSED OF 30% QUARTZ, 60% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; FAIR POROSITY AND PERMEABILITY; NO OIL INDICATORS. 10655' TUFFACEOUS SlLTSTONE = LIGHT TO MEDIUM BROWN GRAY; CLUMPY; STIFF; BLOCKY FRACTURE; SUBPLATY HABIT; EARTHY LUSTER; SILTY TO GRITTY TEXTURE; MASSIVE LAMINAE OF GRADATIONAL SILT AND CLAY COMMON, OCCASIONALLY CARBONACEOUS; COMPOSED OF 60% SILT, 30% CLAY/ASH, AND 10% MIXED MINOR LITHICS; OCCASIONAL CHIPS SHOW STRONG FISSILITY AND PLANAR CHARACTERISTICS. EPOCH 7 ~.~..,~ FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 NOTE: SHORT TRIP 10 STANDS AT 10,732'. 10750' SAND = LIGHT GRAY TO MEDIUM OLIVE GRAY OVERALL COLOR; FINE UPPER TO MEDIUM UPPER CIAST SIZE, RARELY GRADING TO COARSE LOWER; FAIRLY SORTED, SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; FROSTED TO POLISHED TEXTURE; COMPOSED OF 50% CHERT; 40% QUARTZ, AND 10% MINOR MIXED LITHICS; PREDOMINANTLY UNCONSOLIDATED AND GRAIN SUPPORTED; MINOR CLAY MATRIX; FAIR ESTIMATED VISUAL POROSITY; ANY OIL INDICATORS OBSCURED BY OIL- BASED MUD. 10775' COAL = BLACK; FIRM; RESINOUS LUSTER; SMOOTH TEXTURE; TABULAR TO PLATY FRACTURE; PREDOMINANTLY BITUMINOUS; SOME VISIBLE GAS BLEEDING FROM CUTTINGS. 10800' SAND/CONGLOMERATE = LIGHT GRAY; CLAST SIZE RANGES FROM COARSE UPPER TO MEDIUM LOWER; SUBROUND TO SUBANGULAR OCCASIONALLY ANGULAR IN COARSE GRAINS; MODERATE SPHERICITY; POORLY SORTED; IMPACTED TO CHIPPED TEXT; SLIGHT CALCITE AND SILICA CEMENTS; SLIGHT VISIBLE CLAY AND SILT MATRIX; DOMINANTLY GRAIN SUPPORT WITH SECONDARY MATRIX SUPPORT WITH DEPTH; COMPOSED OF 20% QUARTZ, 70% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; POOR TO FAIR POROSITY AND PERMEABILITY; OCCASIONALLY SCATTERED ASH LAMINAE; NO OIL INDICATORS. 10865' TUFFACEOUS CLAYSTONE = MEDIUM GRAY TO BROWNISH GRAY; FIRM; STIFF; PDC GROOVED FRACTURE AND HABIT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; OCCASIONALLY SOFT SEDIMENT DEFORMATION; PLANAR ORIENTATION OF SILTS; COMPOSED OF 70% CLAY, 30% SILT. 10900' SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE LOWER; SBRD TO SUBANGULAR; MODERATE TO POORLY SORTED; MODERATE SPHERICITY; IMPACTED TO CHIPPED TEXTURE; VERY WEAK SILIC CEMENT; VERY SLIGHT CLAY MATRIX; DOMINANTLY GRAIN SUP; COMPOSED OF 50% QUARTZ, 40% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; FAIR TO GOOD POROSITY AND PERMEABILITY; OCCASIONALLY SCATTERED ASH MATRIX; NO OIL INDICATORS. 10955' SAND/SANDSTONE = LIGHT TO MEDIUM DARK GRAY; CLAST SIZE RANGES FROM FINE UPPER TO COARSE LOWER; POOR TO FAIR SORTING; SUBANGULAR TO SUBROUND, LARGER CLASTS OCCASIONALLY ANGULAR; MODERATE SPHERICITY; IMPACTED TO PITTED TEXTURE; MODERATE CLAY MATRIX AND WEAK SILIC CEMENT, BUT DOMINANTLY GRAIN SUPPORTED; COMPOSED OF 50% QUARTZ, 40% CHERT, AND 10% FELDSPAR AND MIXED LITHICS; ESTIMATED POOR VISUAL POROSITY; NO OIL INDICATORS. EPOCH 8 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 11015' COAL/CARBONACEOUS SHALE = BROWN TO BROWNISH-BLACK TO BLACK; MODERATELY HARD TO FIRM; EARTHY TO RESINOUS LUSTER; SMOOTH TO MATTE TEXTURE, OCCASIONALLY ROUGH; GRADES FROM VERY CARBONACEOUS SHALE AT CONTACTS TO COAL; BLOCKY TO CONCOIDAL FRACTURE; COMPOSED OF VERY CARBONACEOUS SHALE AND BITUMINOUS COAL. 11060' COAL = BLACK; FIRM; RESINOUS LUSTER; MATTE TO SMOOTH TEXTURE; CONCOIDAL TO BLOCKY FRACTURE; VISIBLE BLEEDING GAS FROM CUTTINGS; PREDOMINANTLY BITUMINOUS; ABUNDANT CARBONACEOUS SHALE AT UPPER AND LOWER CONTACTS. 11110' SAND = LIGHT TO MEDIUM BROWN GRAY; CLAST SIZE RANGES FROM FINE UPPER TO COARSE LOWER; FAIR SORTING; SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; IMPACTED TO PITTED TEXTURE; WEAK SILIC CEMENT AND DOMINANTLY GRAIN SUPPORTED; SOME MATRIX CLAY COMPOSED OF 60% QUARTZ, 30% CHERT, AND 10% MIXED MINOR LITHICS; ESTIMATED VISUAL POROSITY FAIR; OIL INDICATORS OBSCURED BY OIL- BASED MUD. 11165' COAL = DARK OLIVE BROWN TO BLACK; FIRM TO STIFF; RESINOUS LUSTER; MATTE TO RARELY ROUGH TEXTURE; TABULAR CUTTINGS HABIT; CONCOIDAL TO SUBHACKLY FRACTURE; COMPOSED PREDOMINANTLY OF BITUMINOUS COAL; RARE VISIBLE BLEEDING FROM CUTTINGS. NOTE: HOLE SWEEP AND SHORT TRIP: 5 STANDS AT 11200'. 11215' SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE LOWER; MODERATE SPHERICITY; MODERATE OCCASIONALLY POORLY SORTED; IMPACTED OCCASIONALLY CHIPPED IN LARGER CLASTS; SLIGHT SIL OCCASIONALLY CALC CEMENT; SLIGHT INCR TO MODERATE SILTY/ASHY MATRIX; GRAIN SUP WITH SECONDARY MATRIX SUPPORT; COMPOSED OF 30% QUARTZ, 60% CHERT, 10% METAMORPHIC AND VAR LITHIC FRAGMENTS; FAIR POROSITY AND PERMEABILITY; NO OIL INDICATORS. 11270' COAL/CARBONACEOUS CLAY/SHALE = BLACK TO BROWNISH BLACK TO BROWNISH GRAY AND VAR HUES OF ALL; MASSIVE GRAD BEDS OF COAL BITUMINOUS TO LIGNITIC; GRAD TO VERY CARBONACEOUS SHALE AND CARBONACEOUS CLAY; SOFT TO FIRM; EARTHY TO RESINOUS LUSTER; VARIOUS CONSISTENCIES OF FRACTURE AND HABIT; OVERALL STREAKY OCCASIONALLY SUBLAMINATED WITH CARBONACEOUS SHALE AND CLAY BECOMING SILTY. 11320' SAND = MEDIUM LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE UPPER; SUBROUND; MODERATE SPHERICITY; MODERATE EPOCH 9 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 OCCASIONALLY WELL SORTED; IMPACTED TEXTURE; VERY SLIGHT CALC, PREDOMINANTLY SILIC CEMENT; SLIGHT VISIBLE CLAY/SILT MATRIX; DOMINANTLY GRAIN SUPPORT; COMPOSED OF 50% QUARTZ, 40% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; FAIR POROSITY AND PERMEABILITY; SCATTERED LAMINAE OF VERY CARBONACEOUS SHALE AND CLAY; MINOR ASH. 11375' COAL = BLACK; STIFF; HACKLY TO SUBCONCOIDAL FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO WAXY LUSTER; MATTE TO GRITTY TEXTURE; LIGNITIC TO SUBBITUMINOUS; ABUNDANT GAS BLEED FROM CUTTINGS. 11405' SAND = WHITE LO LIGHT GRAY OVERALL; MOSTLY LOOSE GRAINS OF CLEAR TO MILKY QUARTZ; FAIRLY WELL SORTED; MOSTLY MEDIUM GRAINS WITH MINOR FINE FRACTION; ANGULAR TO SUBROUND; COMPOSED OF 70% QUARTZ, 20% CHERT, AND 10% MIXED VOLCANIC AND METAMORPHIC FRAGMENTS; OIL INDICATORS OBSCURED BY OIL BASED MUD. 11445' TUFFACEOUS CLAYSTONE = DARK YELLOWISH BROWN; MUSHY; EARTHY TEXTURE; IRREGULAR FRACTURE; CURVED HABIT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE UNIFORM LAMINAE, COMPOSED 70% CLAY, 30% SILT; BECOMING MODERATELY HYDROPHILIC WITH DEPTH. NOTE: TRIP FOR BIT AT 11484'. 11490' SAND/CONGLOMERATE = LIGHT GRAY; CLAST SIZE RANGES FROM COARSE UPPER TO MEDIUM UPPER; COARSE GRAIN BECOMING ANGULAR TO SUBANGULAR AND MEDIUM GRAINS SUBROUND TO SUBANGULAR; MODERATE TO POOR SPHERICITY; POOR SORTING; CHIPPED TO IMPACTED TEXTURE; NON TO VERY WEAK SIL CEMENT; SLIGHT TO MODERATE SILT PACKED MATRIX; BOTH GRAIN AND MATRIX SUP COMPOSED OF 20% QUARTZ, 70% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; POOR TO FAIR POROSITY AND PERMEBILITY; OIL INDICATORS MASKED BY OIL BASE MUD. 11555' SAND = LIGHT GRAY; CLAST SIZE RANGES FROM COARSE LOWER TO FINE UPPER; SBANG TO SUBROUND; MODERATE SPHERICITY; VERY POORLY SORTED; IMPACTED TO CHIPPED TEXT; NON TO VERY WEAK SILl(3 CEMENT; NON TO SLIGHT CLAY MATRIX; DOMINANTLY GRAIN SUPPORT; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; FAIR POROSITY WITH FAIR TO GOOD PERMEABILITY; NO OIL INDICATORS. 11610' TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO DARK YELLOWISH BROWN; SOFT; MUSHY; EARTHY FRACTURE; SUBTABULAR TO SUBBLOCKY TO EPOCH 10 FOREST OIL CORPORATION West McArthur River Unit #7-ST #1 SUB NODULAR HABIT; DULL EARTHY LUSTER; CLAY TO SILTY TEXTURE; HOMOGENEOUS BEDS OF CLAY WITH MINOR GRADING TO SILT; COMPOSED OF 70% CLAY, 30% SILT; CARBONACEOUS SPECS IN PARTS. 11650' COAL = BLACK; FIRM TO HARD; RESINOUS LUSTER; SMOOTH TO MATTE TEXTURE; BLOCKY TO HACKLY FRACTURE; COMPOSED OF PREDOMINANTLY BITUMINOUS COAL; VISIBLE BLEEDING GAS IN CUTTINGS. 11680' TUFFACEOUS CLAYSTONE = BROWNISH GRAY; SOFT TO FIRM; STIFF TO MUSHY; EARTHY FRACTURE; SUBNODULAR HABIT; EARTHY LUSTER; CLAYEY; OCCASIONALLY SILTY HABIT; MASSIVE UNIFORM BEDS OF SILTY CLAY; GENERALLY COMPOSED OF 60% CLAY, 30% SILT, 10% CARBONACEOUS FLECKS, MICA AND OTHER DETRITAL MATERIAL. 11735' SAND/SANDSTONE = WHITE TO LIGHT GRAY TO OCCASIONALLY TRANSPARENT; CLAST SIZE RANGES FROM FINE UPPER TO COARSE LOWER; FAIRLY SORTED, SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; MOSTLY MATRIX SUPPORTED WITH COMMON CLAY MATRIX AND WEAK CALCAREOUS CEMENT; COMPOSED OF 60% QUARTZ, 30% CHERT, AND 10% MIXED MINOR LITHICS; POOR ESTIMATED VISUAL POROSITY; OIL INDICATORS OBSCURED BY OIL-BASED MUD. 11790' TUFFACEOUS SlLTSTONE = MEDIUM GRAY TO DARK BROWNISH GRAY; FIRM TO VERY FIRM; BLOCKY CUTTINGS; GRITTY TO ROUGH TEXTURE; SOME ASH; COMPOSED OF 70 % SILT, 20% FINE SAND, AND 10% ASHY CLAY. 11820' SAND = LIGHT GRAY TO MEDIUM GRAY; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER, WITH A SMALL FRACTION OF LOWER FINE; SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; DOMINANTLY GRAIN SUPPORTED WITH WEAK SILIC CEMENT; ABUNDANT LOOSE GRAINS; WEAK CALCAREOUS; COMPOSED OF 30% QUARTZ, 60% CHERT, AND 10% MIXED LITHICS INCLUDING ASH; FAIR ESTIMATED VISUAL POROSITY; OIL INDICATORS OBSCURED BY OIL-BASED MUD 11880' TUFFACEOUS CLAYISlLTSTONE = MEDIUM TO DARK BROWNISH GRAY; SOFT TO FIRM; MUSHY; IRREGULAR TO BLOCKY FRACTURE; BLOCKY CUTTINGS HABIT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; LAMINAR BEDS OF UNIFORM CLAY INTERBEDDED WITH GRAD SILTS AND MINOR COALS. 11920' SAND = LIGHT BROWNISH GRAY TO MEDIUM GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE LOWER, OCCASIONALLY SILT SIZED; SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; POLISHED AND CHIPPED TEXTURE; NON TO VERY WEAK SILIC CEMENT; DOMINANT GRAIN SUPPORT; COMPOSED OF 60% CHERT, 30 % QUARTZ, AND 10% MIXED MINOR LITHICS; FAIR ESTIMATED VISUAL POROSITY; NO OIL INDICATORS. EPOCH 11 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 11970' COAL = BLACK; FIRM, RESINOUS LUSTER; HACKLY TO SUBCONCHOIDAL FRACTURE; SMOOTH TEXTURE; PREDOMINANTLY BITUMINOUS; OCCASIONALLY VISIBLE GAS BLEED; OCCASIONALLY ASH CHIPS. 11995' TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO DARK YELLOWISH BROWN; SOFT TO FIRM; STIFF IN PARTS; EARTHY FRACTURE; SBBLKY TO SUBNODULAR LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE BEDS OF GRAD SILTS AND CLAYS; OCCASIONALLY SCATTERED DEVIT ASH AND VITRIC TUFF NOTE: 6 STAND WIPER TRIP AT 12046'. 12040' SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM FINE UPPER TO VERY FINE UPPER; SBRD; MODERATE SPHERICITY; MODERATE SORTING; IMPACTED TEXTURE; NON TO VERY WEAK SILIC CEMENT; NO VISIBLE MATRIX MATERIAL; DOMINANTLY GRAIN SUPPORT; COMPOSED OF 50% QUARTZ, 40% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; GOOD POROSITY AND PERMEABILITY; NO OIL INDICATORS. 12105' TUFFACEOUS CLAYISlLTSTONE = BROWNISH GRAY TO DARK BROWNISH GRAY; DULL, EARTHY LUSTER; SUBBLOCKY TO SUBPLANAR HABIT; MUSHY TO FIRM; SMOOTH TO GRITTY TEXTURE, DOMINANTLY SILTY. 12135' TUFFACEOUS CLAYSTONE = DARK YELLOWISH BROWN; MUSHY; EARTHY FRACTURE; CURVED HABIT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; MASSIVE UNIFORM LAMINA, COMPOSED 70% CLAY, 30% SILT; BECOMING MODERATELY HYDROPHILIC. 12170' COAL = BLACK; FIRM TO HARD; RESINOUS LUSTER; SMOOTH TO MATTE TEXTURE; BLOCKY TO HACKLY FRACTURE; COMPOSED OF PREDOMINANTLY BITUMINOUS COAL; VISIBLE BLEEDING GAS IN CUTTINGS. NOTE: PUMP HOLE SWEEP AT 12,234'. 12210' TUFFACEOUS CLAYSTONE = MEDIUM GRAY BROWN TO DARK BROWN; LUMPY TO CLUMPY; SOFT TO MUSHY; DULL EARTHY LUSTER; VERY GRITTY TEXTURE; COMPOSED OF 70% CLAY, OCCASIONALLY ASHY, 30% SILT, AND 10% MINOR VERY FINE SAND AND COAL. 12245' SAND = LIGHT TO MEDIUM GRAY OVERALL COLOR; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER WITH A SMALL FRACTION OF COARSE UPPER; SUBROUND; MODERATE SPHERICITY; MODERATELY SORTED; IMPACTED TO CHIPPED TEXTURE; WEAK CLAY MATRIX MATERIAL; DOMINANTLY GRAIN SUPPORTED; NON TO VERY WEAK SILIC CEMENT; COMPOSED OF 50 % QUARTZ, 40% CHERT, AND 10% MIXED MINOR LITHICS; EPOCH 12 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 ESTIMATED VISUAL POROSITY FAIR; OIL INDICATORS OBSCURED BY OIL- BASED MUD. 12305' SAND = TRANSLUCENT TO LIGHT GRAY; CLAST SIZE RANGES FROM FINE LOWER TO MEDIUM UPPER; SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; FAIRLY SORTED; IMPACTED TO CHIPPED TEXTURE, OCCASIONALLY FROSTED; SLIGHT CLAY MATRIX; DOMINANTLY GRAIN SUPPORTED; SLIGHTLY CALCAREOUS; COMPOSED OF 50% QUARTZ, 30% CHERT, AND 10% MIXED MINOR LITHIC FRAGMENTS; FAIR ESTIMATED VISUAL POROSITY; OIL INDICATORS MASKED BY OIL BASED MUD. 12360' TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; SOFT OCCASIONALLY FIRM; OCCASIONALLY STIFF EARTHY FRACTURE; SUBNODULAR HABIT; MODERATE EARTHY LUSTER; CLAYEY OCCASIONALLY SILTY TEXTURE; THICK BEDS OF UNIFORM CLAY WITH OCCASIONALLY SILT SECTIONS; OCCASIONALLY SCATTERED COARSE GRAINED SAND FRAGMANTS. NOTE: TRIP FOR BIT AT 12,387'. 12405' SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM MEDIUM LOWER TO FINE LOWER OCCASIONALLY MEDIUM UPPER TO COARSE LOWER; MODERATE OCCASIONALLY POOR SORTING; MODERATE TO POOR SPHERICITY; H! DEGREE OF IMPACTION AND CHIPPING TEXTURE NON TO VERY WEAK SILIC CEMENT; NON TO SLIGHT VISIBLE ASH MATRIX; DOMINANTLY GRAIN SUPPORT; APPEARS SUBARENACEOUS IN PARTS; COMPOSED OF 40% QUARTZ, 60% CHERT, GOOD POROSITY AND PERM; MINOR LAMINAE OF ASH AND SCATTERED CONGLOMERATE. 12460' COAL = BLACK TO OCCASIONALLY GRAYISH BLACK; FIRM; RESINOUS OCCASIONALLY EARTHY LUSTER; MATTE TEXT; TABULAR TO HACKLY TO SPLINTERY FRACTURE; COMPOSED OF PREDOMINANTLY BITUMINOUS GRADING TO VERY CARBONACEOUS SHALE; VISIBLE BLEEDING GAS. 12490' TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY; SOFT TO FIRM; STIFF IN PARTS; EARTHY FRACTURE; IREG TO EARTHY HABIT; DULL EARTHY LUSTER; SMOOTH OCCASIONALLY SILTY TEXTURE; COMPOSED OF 70% CLAY, 20% SILT, 10% CARBONACEOUS SPECS AND OTHER DETRITAL MATERIAL; OCCASIONALLY VISIBLE PYROCLASTIC RELIC SHARDS IN CLAY MATRIX. 12550' SANDICONGLOMERATEICONGLOMERATE SAND = VERY LIGHT GRAY TO LIGHT GRAY; CLAST SIZE RANGES FROM COARSE LOWER TO FINE UPPER; MODERATE SPHERICITY; SUBANGULAR TO SUBROUND; MODERATE TO POORLY SORTED; POLISHED TO CHIPPED TEXTURE; NON TO VERY SLIGHT SIL CEMENT OCCASIONALLY SEC CALC CEMENT; GRAIN AND MATRIX SUPPORT; NON TO MODERATE MATRIX ASH AND SILT; VARIOUS DEGREES OF POROSITY; EPOCH 13 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 COMPOSED OF 30% QUARTZ, 60% CHERT, N10% METAMORPHIC, FELDSPAR AND VAR LITHIC FRAGS 12610' SAND/CONGLOMERATIC SAND = LIGHT GRAY; CLAST SIZE MEDIUM UPPER TO FINE UPPER; SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; MODERATELY SORTED; CHIPPED TO IMPACTED TEXTURE, OCCASIONALLY POLISHED TEXTURE; NON TO VERY SLIGHT SlLIC CEMENT; NON TO SLIGHT VISIBLE MATRIX SILTS; DOMINANTLY GRAIN SUPPORTED; 30% QUARTZ, 60% CHERT, AND 10% MIXED MINOR LITHICS; GOOD ESTIMATED VISUAL POROSITY; OIL INDICATORS OBSCURED BY OIL-BASED MUD. 12670' SAND/CONGLOMERATIC SAND = LIGHT TO MEDIUM GRAY; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER; SUBROUND TO ROUND; MODERATE SPHERICITY; BIT IMPACTED AND CHIPPED TEXTURE, LOCALLY FROSTED; VERY WEAK SlLIC CEMENT AND RARE CLAY MATRIX; DOMINANTLY GRAIN SUPPORTED COMPOSED OF 50% QUARTZ, 40% CHERT AND 10% MINOR MIXED LITHICS; ESTIMATED VISUAL POROSITY AND PERMEABILITY IS GOOD OIL INDICATIONS OBSCURED BY OIL-BASED MUD. 12730' SAND = TRANSLUCENT TO LIGHT GRAY TO WHITE; FINE UPPER TO COARSE LOWER; FAIRLY SORTED; SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; GRAINS HAVE AN IMPACTED TO FROSTED TEXTURE; PREDOMINANTLY GRAIN SUPPORTED WITH WEAK SILIC CEMENT AND CLAY MATRIX; COMPOSED OF 60% CHERT, 30% QUARTZ, AND 10% MINOR LITHICS; VISUAL ESTIMATED POROSITY AND PERMEABILITY IS FAIR; OIL INDICATORS OBSCURED BY OIL-BASED MUD. 12785' CONGLOMERATIC SAND = LIGHT MEDIUM GRAY TO MEDIUM BROWN GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO PEBBLE; POOR TO FAIR SORTING; SUBROUND TO ROUNDED; PITTED AND IMPACTED TEXTURE; DOMINANTLY GRAIN SUPPORTED WITH WEAK CLAY MATRIX; COMPOSED OF 40% CHERT, 50% QUARTZ, AND 10% MIXED LITHICS, INCLUDING FELDSPAR AND METAVOLCANICS; NO ESTIMATED VISUAL POROSITY; OIL INDICATORS MASKED BU OIL BASED MUD. 12835' COAL = BLACK TO OCCASIONALLY GRAYISH BLACK; FIRM; RESINOUS OCCASIONALLY EARTHY LUSTER; MATTE TEXT; TABULAR TO HACKLY TO SPLINTERY FRACTURE; BITUMINOUS. 12860' SAND = TRANSLUCENT TO LIGHT GRAY TO WHITE; FINE UPPER TO COARSE LOWER; FAIRLY SORTED; SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; GRAINS HAVE AN IMPACTED TO FROSTED TEXTURE; PREDOMINANTLY GRAIN SUPPORTED WITH WEAK SILIC CEMENT AND CLAY MATRIX; COMPOSED OF 90% QUARTZ, 10% LITHICS; VISUAL ESTIMATED POROSITY AND IS FAIR; OIL INDICATORS OBSCURED BY OIL-BASED MUD. EPOCH 14 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 12915' COAL = BLACK OCCASIONALLY GRAYISH BLACK; FIRM; RESINOUS TO OCCASIONALLY EARTHY LUSTER; MATTE TEXT; TABULAR TO HACKLY TO SPLINTERY FRACTURE; BITUMINOUS; APPEARS TO BE CAVING FROM UPHOLE. NOTE: SET 7 5/8" LINER SHOE AT 12,950'. 12970' CEMENT CONTAMINATION = GRAYISH BROWN; FIRM TO STIFF; EARTHY TO SUBPLANAR FRAC; SUBTABULAR TO SUBBLOCKY HABIT; EARTHY LUSTER; SILTY TO SUCROSIC AND GRITTY TEXTURE; COFFEE GROUND APPEARANCE; OCCASIONALLY SAND, CLAY, ASH TUFF AND COAL FRAGMENTS. 13020' CONGLOMERATIC SAND = LIGHT MEDIUM GRAY TO MEDIUM BROWN GRAY; CLAST SIZE RANGES FROM LOWER FINE TO UPPER COARSE LPWER TO PEBBLE; POOR SORTING; ANGULAR TO MIN SUBANGULAR; PITTED AND IMPACTED TEXTURE; DOMINANTLY GRAIN SUPPORTED WITH WEAK CLAY MATRIX; COMPOSED OF 80%QTZ, 10% CHERT, AND 10% MIXED LITHICS; SEEN DOMINANTLY AS LOOSE OR BROKEN GRAINS; NO ESTIMATED VISIBLE POROSITY; OIL INDICATORS MASKED BY OIL BASED MUD. NOTE: TRIP FOR BIT AT 13,073'. 13095' SAND = TRANSLUCENT TO LIGHT GRAY TO MEDIUM BROWN GRAY; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER/COARSE LOWER; MODERATE SORTED; MODERATE SPHERICITY; GRAINS GENERALLY HAVE A PITTED TO IMPACTED TEXTURE; SUBANGULAR TO SUBROUND; DOMINANTLY MATRIX SUPPORTED WITH WEAK CLAY AND ASH CEMENT IN MATRIX; COMPOSED OF 70% QUARTZ, 20% CHERT, AND 10% MIXED LITHICS; ESTIMATED VISUAL POROSITY FAIR TO GOOD; OIL INDICATORS OBSCURED BY OIL-BASED MUD. NOTE: PROBABLE INACCURATE GAS CHROMATOGRAPHY BETWEEN 13,159' AND 13,170'; GAS TRAP MOTOR INOPERABLE; REPLACED MOTOR. NOTE: TRIP FOR BIT AT 13,195.' 13200' SAND = LIGHT GRAY TO MEDIUM BROWN GRAY; CLAST SIZE FROM FINE UPPER TO MEDIUM UPPER WITH OCCASIONALLY CONGLOMERITIC FRACTION; SUBANGULAR TO SUBROUND; MODERATE SORTED, MODERATE SPHERICITY; DOMINANTLY GRAIN SUPPORTED WITH NO TO WEAK MATRIX CLAY AND CALCAREOUS CEMENT; COMPOSED OF 70% QUARTZ, 20% CHERT AND 10% MIXED LITHICS; ESTIMATED VISUAL POROSITY FAIR TO GOOD; NO SHOWS. NOTE: LWD TOOL FAILURE; TRIP TO REMOVE LWD AND TRIP FOR BIT AT 13,256'. [:1 EPOCH 15 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 13280' SAND = WHITE TO MEDIUM GRAY; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER; FAIRLY SORTED; SUBANGULAR TO SUBROUND; WEAK TO MODERATE SPHERICITY; GRAINS ARE BIT IMPACTED AND ABRADED; COMPOSED OF 70 % QUARTZ, 20% CHERT, AND 10% MIXED LITHICS; ESTIMATED VISUAL POROSITY FAIR TO GOOD; LITTLE CEMENTATION OBSERVED; OIL INDICATORS OBSCURED BY OIL-BASED MUD. NOTE: TRIP FOR BIT AT 13,354'. 13355' SAND = WHITE TO MEDIUM GRAY; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER; FAIRLY SORTED; SUBANGULAR TO SUBROUND; WEAK TO MODERATE SPHERICITY; GRAINS ARE BIT IMPACTED AND ABRADED; COMPOSED OF 60 % QUARTZ, 20% CHERT, AND 20% MIXED LITHICS; ESTIMATED VISUAL POROSITY FAIR TO GOOD; LITTLE CEMENT NOTED; OIL INDICATORS OBSCURED BY OIL-BASED MUD. 13420' SAND = LIGHT GRAY WHITE TO MEDIUM BROWN GRAY; CLAST SIZE RANGES FROM FINE LOWER TO MEDIUM LOWER WITH A DISTINCT SILT FRACTION (10-20%); TEXTURALLY AND COMPOSITONALLY SUBMATURE; POOR TO FAIRLY SORTED; SUBROUND TO SUBANGULAR; LOW SPHERICITY; GRAINS ARE STRONGLY BIT IMPACTED AND PULVERIZED IN PLACES; COMPOSED OF 60% QUARTZ, 30% CHERT, AND 10% MIXED LITHICS; ESTIMATED VISUAL POROS FAIR; NO OIL INDICATORS. 13470' SAND = LIGHT GRAY WHITE TO MEDIUM BROWN GRAY; CLAST SIZE RANGES FROM FINE LOWER TO MEDIUM LOWER WITH A DISTINCT SILT FRACTION (10-20%); POOR TO FAIRLY SORTED; SUBROUND TO SUBANGULAR; LOW SPHERICITY; GRAINS ARE STRONGLY BIT IMPACTED AND PULVERIZED IN PLACES; COMPOSED OF 80% QUARTZ, 10% CHERT, AND 10% MIXED LITHICS; ESTIMATED VISUAL POROSITY FAIR; NO OIL INDICATORS. 13535' SAND = TRANSLUCENT TO MEDIUM GRAY; CLAST SIZE RANGES FROM FINE LOWER TO MEDIUM LOWER; SORTING IS FAIR TO GOOD; SUBANGULAR TO SUBROUND; POOR TO MODERATE SPHERICITY; STRONG BIT IMPACTED TEXTURE, LOCALLY PULVERIZED; DOMINANTLY GRAIN SUPPORTED WITH NO APP MATRIX CEMENT; COMPOSED OF 70% QUARTZ, 20% CHERT, AND 10% MIXED LITHICS, INCLUDING METALITHICS; ESTIMATED VISUAL POROSITY AND PERMEABILITY IS GOOD; OIL INDICATORS OBSCURED BY OIL-BASED MUD 13585' SAND = LIGHT TO MEDIUM BROWN GRAY; CLAST SIZE FROM FINE LOWER TO MEDIUM UPPER; POOR TO FAIR SORTING; LOW SPHERICITY; ANGULAR TO SUBANGULAR; STRONG BIT IMPACTED TEXTURE; DOMINANTLY GRAIN SUPPORTED; COMPOSED OF 70% QUARTZ, 20% CHERT, AND 10% MIXED LITHICS; ESTIMATED VISUAL POROSITY FAIR TO GOOD; OIL INDICATORS OBSCURED BY OIL-BASED MUD. EPOCH 16 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 NOTE: PUMP HI-VIS HOLE SWEEP AT 13,641' 13650' SAND = LIGHT TO MEDIUM BROWN GRAY; CLAST SIZE FROM FINE LOWER TO MEDIUM UPPER; POOR TO FAIR SORTING; LOW SPHERICITY; ANGULAR TO SUBANGULAR; STRONG BIT IMPACTED TEXTURE; DOMINANTLY GRAIN SUPPORTED; COMPOSED OF 90% QUARTZ AND 10% CHERT; ESTIMATED VISUAL POROSITY FAIR TO GOOD; OIL INDICATORS OBSCURED BY OIL-BASED MUD. 13710' CONGLOMERATIC SAND = LIGHT MEDIUM GRAY TO LIGHT BROWN GRAY; CLAST SIZE RANGES FROM LOWER FINE TO UPPER COARSE; POOR SORTING; ANGULAR TO SUBANGULAR; PITTED AND IMPACTED TEXTURE; DOMINANTLY GRAIN SUPPORTED WITH WEAK CLAY MATRIX; COMPOSED OF 80%QUARTZ, 10% CHERT, AND 10% MIXED LITHICS; NO OIL INDICATORS 13765' SAND = TRANSLUCENT TO LIGHT BROWN GRAY; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER; FAIR TO FAIRLY WELL SORTED; SUBANGULAR TO SUBROUND; LOW TO MODERATE SPHERICITY; CLASTS SHOW STRONG BIT IMPACTED AND CHIPPED TEXTURE; GRAIN SUPPORTED WITH NON TO WEAK MATRIX CLAYS AND/OR CEMENT; COMPOSED OF 70% QUARTZ, 30% CHERT, WITH MINOR MIXED LITHICS; ESTIMATED PERM AND POROSITY IS FAIR TO GOOD; OIL INDICATORS OBSCURED BY OIL-BASED MUD. 13815' CONGLOMERATIC SAND = LIGHT MEDIUM GRAY TO LIGHT BROWN GRAY; CLAST SIZE RANGES FROM LOWER FINE TO UPPER COARSE; POOR SORTING; ANGULAR TO SUBANGULAR; PITTED AND IMPACTED TEXTURE; DOMINANTLY GRAIN SUPPORTED WITH WEAK CLAY MATRIX; COMPOSED OF 80%QUARTZ, 10% CHERT, AND 10% MIXED LITHICS; NO OIL INDICATORS. NOTE: TRIP FOR BIT AT 13,857'. 13885' SAND/CONGLOMERATIC SAND = LT TO MEDIUM BRN GRAY; CLASTS RANGE FROM FINE LOWER TO FINE UPPER, FAIRLY SORTED; SUBANGULAR TO SUBROUND; LOW TO MODERATE SPHERICITY; MODERATE SORTING; ABRADED AND BIT IMPACTED TEXTURE; DOMINANTLY GRAIN SUPPORTED WITH WEAK CLAY MATRIX; COMPOSED OF 60% QUARTZ, 40% CHERT; ESTIMATED VISUAL POROSITY FAIR TO GOOD; OIL INDICATORS OBSCURED BY OIL BASED MUD. NOTE: TRIP FOR LWD TOOL CHANGEOUT AT 13,917'. 13940' SAND = TRANSLUCENT TO LIGHT BROWN GRAY; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER; FAIR TO FAIRLY WELL SORTED; SUBANGULAR TO SUBROUND; LOW TO MODERATE SPHERICITY; CLASTS SHOW STRONG BIT IMPACTED AND CHIPPED TEXTURE; GRAIN SUPPORTED WITH NON TO WEAK MATRIX CLAYS AND/OR CEMENT; COMPOSED OF 70% EPOCH 17 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 QUARTZ, 30% CHERT, WITH MINOR MIXED LITHICS; ESTIMATED PERM AND POROSITY IS FAIR TO GOOD; OIL INDICATORS OBSCURED BY OIL-BASED MUD. 14000' TUFFACEOUS SILTSTONE = MEDIUM GRAY TO DARK BROWNISH GRAY; FIRM TO VERY FIRM; BLOCKY CUTTINGS; GRITTY TO ROUGH TEXTURE; SOME ASH; COMPOSED OF 70 % SILT, 10% FINE SAND, AND 20% ASHY CLAY. 14030' SAND = TRANSLUCENT TO LIGHT WHITE TO LT BRN GRAY COLOR; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM UPPER, FAIR TO WELL SORTED, SUBROUND TO ROUNDED, MODERATE SPHERICITY; WEAK TO MODERATE BIT IMPACTED TEXTURE; DOMINANTLY GRAIN SUPPORTED WITH WEAK TO NON-EXISTENT CLAY MATRIX OR CEMENT MATERIAL; COMPOSED OF 70% QUARTZ, 30% CHERT, AND MIXED MINOR LITHICS; ESTIMATED VISUAL PERMEABILITY AND POROSITY GOOD; OIL INDICATORS OBSCURED BY OIL- BASED MUD. NOTE: TRIP FOR BIT AT 14,099'. 14110' SAND = DARK GRAY TO BROWNISH GRAY COLOR; LOWER MEDIUM TO UPPER FINE GRAINED CLASTS; SUBROUNDED TO ROUNDED; COM BIT IMPACTED TEXTURE; DOMINANTLY MATRIX SUPPORTED; MODERATE SPHERICITY; 70% QUARTZ, 20% CHERT, 10% METANOLC FRAGMENTS; ESTIMATED VISUAL PERMEABILITY AND POROSITY GOOD; OIL INDICATORS MASKED BY OIL-BASED MUD. 14155' TUFFACEOUS CLAYSTONE = MEDIUM GRAY TO BROWNISH GRAY; FIRM TO MODERATE FIRM BLOCKY CTGS; EARTHY LUSTER; CLAYEY TO SLIGHTLY SILTY TEXTURE; OCCASIONALLY ASH; DOMINANTLY CLAY SIZED GRAINS, OCCASIONALLY SILTY GRAINS. 14185' SAND = MEDIUM GRAY TO BROWNISH GRAY; DOMINANTLY TRANSL TO WHITE GRAINS, OCCASIONALLY GRAY AND GREENSTONE; VERY FINE TO UPPER MEDIUM CLASTS, OCCASIONALLY COURSE GRAINS; MODERATE WELL SORTED; SUBROUNDED TO SUBANGULAR; DOMINANTLY GRAIN SUPPORTED WITH OCCASIONALLY CLAY MATRIX; COMPOSED OF 70% QUARTZ, 30% CHERT, MINOR LITHIC FRAGMENTS; ESTIMATED POROSITY AND PERMEABILITY IS POOR; OIL INDICATIRS OBSCURED BY OIL-BASED MUD. TD AT 14,273 FEET AT 3:00PM ON 4/4/2001 IN THE HEMLOCK FORMATION. CIRCULATE OUT SAMPLES AT 5:45 PM. [::1 EPOCH 18 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 DALLY CHRONLOGY 2/2312001 FINISH MAKING UP BHA FOR DRILLING OUT CEMENT PLUG, RUN IN HOLE TO 810', TEST MWD, RUN IN HOLE, LOOK FOR CEMENT PLUG FROM 9785' TO 10005' = TAG CEMENT, CIRCULATE HOLE CLEAN, DRILL CEMENT FROM 10005' TO 10029', CIRCULATE HOLE CLEAN, PUMP DRY JOB AND TRIP OUT TO SHOE, MONITOR WELL, TRIP OUT OF THE HOLE, LAY DOWN BHA, SERVICE AND CLEAN RIG, CEMENT SET UP DEEPER THAN KICK OFF POINT, TRIP IN HOLE TO SPOT ANOTHER CEMENT PLUG. 2124/2001 RUN IN HOLE TO SPOT CEMENT PLUG AT 10025', CIRCULATE AND CONDITION MUD AT 10025', PUMP 3 BBLS H20, TEST LINES TO 3000 PSI, PUMP 3.5 BBLS OF H20 AND 36.1 BBLS OF CEMENT DISPLACED WITH 167 BBLS OF MUD, PULL 10 STANDS, DROP DART, CIRCULATE BOTTOMS UP, MONITOR WELL, PULL OUT TO THE SHOE AND MONITOR THE WELL, TRIP OUT OF THE HOLE, TRIP IN WITH HWDP TO THE SHOE, CUT AND SLIP DRILL LINE, TRIP IN TO 9313', CIRCULATE MUD AND TAG CEMENT PLUG AT 9662', CIRCULATE AND CONDITION MUD. 212512001 LOOK FOR HARD CEMENT FROM 9662' TO 9738', CIRCULATE MUD AND WAIT ON CEMENT, LOOK FOR HARD CEMENT FROM 9738' TO 9820', BEGIN SLIDING AND ROTATING IN NEW FORMATION. 2/2612001 DRILL TO 10096, CIRCULATE CUTTINGS OUT, TRIP OUT TO SHOE, MONITOR WELL, PULL OUT OF THE HOLE, LAY DOWN HWDP, BHA AND MWD, CHANGE BIT AND RUN IN THE HOLE WITH BHA AND DRILL PIPE. 2127/2001 RUN IN HOLE TO 9769', FILL PIPE AND ORIENTATED TOOL THROUGH KOP, REAM TO BOTTOM, DRILL FORMATION. 212812001 DRILL FORMATION TO 10731', CIRCULATE BOTTOM'S UP AND SHORT TRIP, PUMP HI VIS SWEEP ON BOTTOM AND DRILL AHEAD. 31112001 DRILL TO 11015', PUMP SWEEP, DRILL TO 11199', CIRCULATE SWEEP AND PULL 5 STAND SHORT TRIP, DRILL AHEAD. [::1 EPOCH 19 312/2001 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 DRILL AHEAD TO 11484', CIRCULATE SWEEP BOTTOM'S UP, PULL FOUR STANDS OFF BOTTOM AND CIRCULATE BOTTOM'S UP, MONITOR WELL, PULL OUT OF HOLE FOR BIT TRIP. 31312001 CONTINUE TO PULL OUT OF THE HOLE TO 6520', MONITOR THE WELL AND PULL OUT OF THE HOLE, RIG UP AND TEST BOP'S, LAY DOWN BIT, MOTOR AND JARS, PICK UP NEW MOTOR, JARS AND BIT, RUN HWDP, CHANGE FLOAT AND STAB ON MOTOR, RUN IN HOLE, CUT AND SLIP DRILL LINE, RUN IN HOLE, REAM LAST 2 STANDS, CIRCULATE BOTTOMS UP TO WARM OIL BASE MUD, DRILL AHEAD. 31412001 DRILL AHEAD TO 11786', CIRCULATE SWEEP, DRILL AHEAD TO 12030'. 3151200,1 CONTINUE DRILLING TO 12043', SHORT TRIP TO 11391', DRILL AHEAD TO 12233', CIRCULATE SWEEP, DRILL AHEAD TO 12387', CIRCULATE BOTTOMS UP, MONITOR WELL, BEGIN TO PULL OUT OF HOLE FOR BIT TRIP. 3/6/2001 PULL OUT OF THE HOLE, CHANGE BIT, RUN IN HOLE, SERVICE TOP DRIVE, RUN IN HOLE AND REAM FROM 12234' TO 12388', DRILLING FORMATION TO 12480'. 31712001 DRILLED 12480' TO 12950'. CIRCULATED BOTTOMS UP FOR GEOLOGIST. LOGGING/CASING POINT CALLED BY GEOLOGIST AT 12950'. PUMPING HI VIS SWEEP. 31812001 PUMPED HI VIS SWEEP. PULLED OUT OF HOLE. RIGGED UP SCHLUMBERGER. RAN QUAD COMBO ELECTRIC LOGS. RUNNING IN HOLE FOR WIPER TRIP. 31912001 RAN TO BOTTOM OF HOLE. PUMPED HI VIS SWEEP. CIRCULATED HOLE CLEAN. SHORT TRIP TO SHOE. WIPED HOLE TO BOTTOM. PULLING OUT OF HOLE. 311012001 PULLED OUT OF HOLE. LAID DOWN HEAVY WALL DRILL PIPE AND BHA. RIG UP WEATHERFORD TO RUN CASING. RUNNING CASING. EPOCH 20 311112001 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 RUNNING CASING. 3112/2001 CEMENTED 7 518' (7.625") CASING, TOP AT 6321', BASE AT 12,946'. PULLING OUT OF HOLE, LAYING DOWN 5" DRILL PIPE. 311312001 PULLED OUT OF HOLE. CHANGED RAMS ON BOP. TESTED BOP. PICKING UP 3 %" DRILL PIPE. 311412001 RAN IN HOLE WITH 3.5" DRILL PIPE. PERFORMED CASING PRESSURE TEST- PASSED. PULLED OUT OF HOLE. PICKED UP MUD MOTOR. RAN IN HOLE TO DRILL OUT CEMENT AT 7 5/8" (7.625") CASING SHOE. 311512001 DRILLED OUT LANDING COLLAR AT 7 518" SHOE. DRILLED 12950 TO 12974 FEET. PERFORMED FIT TEST TO 10.5 PPG EQUIVALENT. DRILLED 12974 TO 13050 FEET. 3/1612001 DRILLED 13050 TO 13073 FEET. PULLED OUT OF HOLE FOR NEW BHA. MADE UP NEW BHA. RUNNING IN HOLE. 3/1712001 RAN IN HOLE. DRILLED (SLIDE) 13073 TO 13193 FEET. 31'18/2001 DRILLED 13193 TO 13195 FEET. PULLED OUT OF HOLE FOR NEW BIT. RUNNING IN HOLE. 311912001 DRILLED 13195 TO 13246 FEET. LWD TOOL FAILED TO OPERATE. PULLING OUT OF HOLE. 3120/2001 PULLED OUt Of HOLE. LAID DOWN BHA. TEST BOP. PICKED UP BHA (WITHOUT LWD TOOL). RAN IN HOLE. DRILLED AHEAD (SLIDE) FROM 13246 TO 13275 FEET. 3121/2001 [::1 EPOCH 21 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 DRILLED AHEAD FROM 13275 TO 13354 FEET. CIRCULATED BOTTOMS UP. PULLED UP TO 7 5/8" CASING SHOE. PUMPED DRY JOB. PULLING OUT OF HOLE FOR NEW BIT/BHA. 3122/2001 PULLED OUT OF HOLE. PICKED UP LWD TOOL. RAN IN HOLE TO 7 518' SHOE. SLIPPED AND CUT DRILL LINE. CONTINUED RUNNING IN HOLE, MADE MAD PASS THROUGH UNLOGGED SECTION OF HOLE BELOW 7 5/8" SHOE. DRILLED 13354 TO 13359 FEET. UNABLE TO GET FACE SIGNAL FROM MWD TOOL. PULLING OUT OF HOLE. 3/23/2001 PULLED OUT OF HOLE. CHECKED AND SERVICED MWD. RAN IN HOLE WITH 3.5" DRILL PIPE, TEST MWD. RAN IN HOLE WITH 5" DRILL PIPE, TESTING MWD EVERY TEN STANDS, NOISE INCREASING WITH DEPTH. ATTEMPTED SURVEY AT 7 5/8" SHOE- FAILED. DROPPED POS DART AND PUMPED DRY JOB. PULLING OUT OF HOLE. 3/24/2001 PULLED OUT OF HOLE. LAID DOWN LWD TOOL. RUN IN HOLE WITH BHA, SURFACE TEST MWD. RUN IN HOLE, TEST MWD @ 3500'. SERVICE RIG. RUN IN HOLE, TEST MWD @ SHOE. RUN IN HOLE TO TD, HOLE IN GOOD SHAPE. ON BOTTOM @ 19:30 HOURS. DRILL FROM 13359' TO 13400'. 312512001 DRILLED (SLIDE) 13400 TO 13480 FEET. CIRCULATED BOTTOMS UP. PULLED INTO 7 5/8" SHOE. PUMPED POS DART. PUMPED DRY JOB. PULLING OUT OF HOLE FOR NEW BIT. 3/26/2001 PULLED OUT OF HOLE FOR NEW BIT (#24). ADDED THRUSTER MWD TOOL TO BHA. TRIPPED INTO HOLE. DRILLED (SLIDE) 13480 TO 13515 FEET. WORKING ON TOP DRIVE. 312712001 REPAIR TOP DRIVE. RUN IN HOLE. DRILL AHEAD (ROTATE) FROM 13515 TO 13643 FEET. PUMP HI-VIS SWEEP WHILE ROTATING AND RECIP. DRILL AHEAD FROM 13643 TO 13656 FEET. PULL OUT OF HOLE FOR BIT. 3128/2001 PULLED OUT Of HOLE FOR NEW BIT. TEST BOP'S. RAN IN HOLE. WASHED AND REAMED 13421 TO 13425 FEET. REAMED BOTTOM 56 FEET. DRILLED 13656 TO 13725 FEET. 312912001 EPOCH 22 ~ FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 DRILLED 13725 TO 13857 FEET. PUMPED HI VIS SWEEP. PULLING OUT OF HOLE. 313012001 CONTINUE CIRCULATING SWEEPS. MINIMAL CUTTINGS RETURNED, HOLE CLEANED UP PRIOR TO COMING AROUND. PULL OUT OF HOLE. PICK UP MWD & AVl TOOL, PROBLEM WITH LWD TOOL. RUN IN HOLE TO SHOE. 3131/2001 SLIPPED AND CUT DRILL LINE. RETEST MWD TOOL AT 7 5/8" SHOE. ORIENT HIGH SIDE AND RAN IN HOLE, REAMING FROM 13749 FEET TO BOTTOM. TAGGED BOTTOM AND PUMPED SURVEY. MWD FAILURE. DRILLED FROM 13871 TO 13909 FEET. ATTEMPTED MWD SURVEY- FAILED. DRILLED FROM 13909 TO 13917 FEET. MADE MAD PASS FROM 13917 TO 13225 FEET. PULLED INTO 7 5~8" SHOE. PUMPED POS DART AND DRY JOB. PULLING OUT OF HOLE. 4/01/2001 PULLED OUT OF HOLE. RAN IN HOLE (NEW BIT ~r27), TESTING MWD TOOL - OKAY. DRILLED 13917 TO 14025 FEET. 4102/2001 DRILLED 14025 TO 14099 FEET. PUMPED HI ViS SWEEP. PULLING OUT OF HOLE FOR NEW BIT (#28). 41031200! RAN IN HOLE, TESTING MWD TOOL- OKAY. DRILLED 14099 TO 14150 FEET. 410412001 DRILLED 14150 TO 14273 (TD). CIRC, MONITOR WELL. POH TO SHOE @12950 FEET. MONITOR WELL, DROP DART, PUMP PILL. PULLING OUT OF HOLE. 410512001 PULLED OUT OF HOLE. BOP TEST- OKAY. WIPER RUN WITH BULL NOSE ROLLER REAMER. EXTREMELY HARD REAMING. REAMED TO 13150 FEET. 41061200t CIRCULATE. PULLED OUT OF HOLE FOR NEW BHA. RAN IN HOLE. REAMED OUT HOLE. CIRCULATE. 4107/2001 PULLED OUT OF HOLE. LAY DOWN BHA. P/U HWDP, WEATHERFORD TOOLS. RAN IN HOLE WITH 4.5" LINER. P/U LINER HANGER. ClRC TO HANGER. CONTINUE TO RUN IN HOLE WITH DRILLING PIPE, LINER, AND HANGER. EPOCH 23 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 410812001 RUN IN HOLE WITH 4.5' SLOTTED LINER AND HANGER. CIRC AND COND MUD AT 12946 FEET. CONTINUE TO RUN IN HOLE, TAGGED BOTTOM. SET HMC HANGER. PULLING OUT OF HOLE, LAYING DOWN DRILL PIPE, SUCKING OIL BASE MUD FROM PIPE. 410912001 P/U 2 7/8" TUBING. RUNNING IN HOLE WITH TUBING. 411012001 CONTINUE TO RUN IN HOLE WITH 2 7/8" TUBING TO 12467 FEET. 4111/2001 CONTINUE TO RUN IN HOLE WITH 2 7/8" TUBING FROM 12467 TO BOTTOM. ATTEMPT PRESSURE TEST, FAIL. CIRC BOTTOMS UP. ATTEMPT ANOTHER PRESSURE TEST, FAIL. CIRCULATE. ATTEMPT PRESSURE TEST- NO TEST. PULL OUT OF HOLE WITH 2 7/8" TUBING. 4/12/2001 LID PUMP caVITY AND BAKER SEAL ASSEMBLY. P/U DUMMY SEAL ASSEMBLY. RUN IN HOLE WITH 2 7/8" TUBING. PRESSURE TEST- NO GOOD. PULL OUT OF HOLE WITH 2 7/8" TUBING. 411312001 I_/D DUMMY SEAL ASSEMBLY. TEST BOP'S. RUN IN HOLE WITH 2 718" TUBING AND BAKER SEAL ASSEMBLY. PRESSURE TEST - NO GOOD. CIRC MUD. 411412001 CONTINUE TO CIRCULATE MUD. RIG UP WIRE LINE AND RUN IN HOLE WITH 1 %" TOOLS TO 12400 FEET. PULL OUT OF HOLE WITH WIRE LINE AND RIG DOWN. PUMP PILL. PULL OUT OF HOLE WITH 2 7~8" TUBING. 411512001 CONTINUE TO PULL OUT OF HOLE WITH 2 718' TUBING. L/DN SEAL ASSEMBLY. TEST PUMP CAVITY TO 1500 PSI FOR 5 MINUTES. RIG DOWN TEST EQUIP. M/U BAKER PACKER, I JT 2 718" TUBING, PUMP CAVITY. RUN IN HOLE WITH 2 7~8" TUBING AND PACKER ASSEMBLY. PRESSURE TEST- NO GOOD. 4/16/2OOl EPOCH 24 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 PULL OUT OF HOLE WITH 2 718' TUBING AND PACKER. CHECK PACKER. RUN IN HOLE WITH 2 7/8" TUBING AND PACKER. 411712001 CONTINUE TO RUN IN HOLE WITH 2 7/8" TUBING AND PACKER. PRESSURE TEST- GOOD. RUN IN HOLE WITH WIRELINE TO RETRIEVE DUMMY TOOLS. EPOCH 25 SURVEY RECORD Measured TVD Inclination Azimuth Coordinates Dog Leg Depth Feet Feet De~lrees Degrees E(+) W(-) N(+) S(-) Degrees130' 12439.62 9038.31 44.56 89.13 5468.83 E 4152.08 N 6.47 12533.93 9106.23 43.44 79.65 5533.88E 4158.42N 7.08 12627.41 9175.31 41.39 70.39 5594.67E 4174.59N 7.02 12720.99 9246.38 39.93 59.97 5649.88E 4200.03N 7.42 12811.61 9316.19 39.40 51.36 5697.56E 4232.57N 6.09 12872.62 9363.37 39.28 52.11 5727.93E 4256.52N 0.80 12950.28 9423.44 39.39 52.11 5766.78E 4286.76N 0.14 i 13011.64 9467.75 48.02 52.37 5800.27E 4312.69N 14.07 13041.55 9486.87 52.53 52.69 5818.52E 4326.67N 15.10 i i 13066.82 9501.46 56.87 53.54 5835.02E 4339.04N 17.39 i i 13109.87 9522.46 65.32 54.42 5865.28E 4361.38N 19.66 i 13140.03 9532.95 73.24 55.58 5888.33E 4377.60N 26.55 i 13177.08 9540.36 83.65 54.90 5918.11E 4398.27N 28.15 13194.00 9541.89 87.63 55.00 5931.96E 4407.83N 26.68 ' ' 13227.05 '9543.01 '90.25 53.52 5958.56E 4427.43N 13.49 i 13264.30 9542.07 92.65 50.05 5987.81E 4450.46N 11.32 13289.83 9540.39 94.91 49.10 6007.20E 4466.98N 9.60 13318.32 9537.49 96.67 46.44 6028.33E 4485.91N 11.14 13352.20 9533.18 97.94 44.28 6052.24E 4509.52N 7.36 13384.67 9529.16 96.29 43.48 6074.57E 4532.74N 5.65 13411.84 9526.12 96.67 43.31 6092.98E 4552.48N 1.53 i i i 13428.68 9524.41 95.00 43.41 6104.48E 4564.66N 9.93 ii i 13441.61 9523.35 94.38 42.83 6113.29E 4574.06N 6.56 i i i 13459.81 9522.13 93.30 42.55 6125.60E 4587.41N 6.13 t3475.14 9518.27 91.88 41.67 6135.93E 4598.71N t0.86 i i i 13498.82 9521.00 89.63 41.78 6151.76E 4616.46N 9.48 ' 13515.52 9523.89 87.57 41.80 6162.82E 4628.83N 12.44 13532.58 9525.00 85.53 41.46 6174.13E 4641.56N 12.08 13546.77 9526.16 85.13 41.17 6183.46E 4652.18N 3.49 13566.47 9527.80 85.31 40.85 6196.35E 4666.99N 1.86 13583.28 ' '9529.15 85.46 40.97 6207.32E 4679.66N 1.18 13601.35 9527.94 85.95 41.17 6219.16E 4693.24N 2.94 13640.75 9530.44 86.76 41.14 6245.04E 4722.84N 2.05 13670.65 9532.23 86.36 40.67 6264.58E 4745.40N 2.06 13703.25 9534.56 85.90 41.08 6285.81E 4770.04N 1.89 13733.54 9536.97 84.97 40.61 6305.56E 4792.89N 3.44 13770.90 9540.32 84.75 40.46 6329.74E 4821.17N 0.71 FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 Measured TVD Inclination Azimuth Coordinates Dog Leg Depth Feet Feet De~lrees Degrees E(+) W(-) N(+) S(-) Degreesl30' 13806.13 9542.96 86.64 40.43 6352.53E 4847.90N 5,37 14011.79 9550.34 86.92 41.50 6487.50E 5002.88N 2.04 14048.84 9551.73 88.77 41.80 6512.10E 5030,55N 5.06 , 14082.28 9552.58 88.34 41.92 6534.41E 5055.44N 1.34 14110.94 9553.44 88.21 41.17 6553.41E 5076,89N 2.66 14139.89 9554.64 87.04 39.76 6572.18E 5098,89N 6.32 14170.30 9556.22 86.98 38.98 6591.44E 5122.37N 2.57 14203.09 9557.88 87.23 39.25 6612.t0E 5147,78N 1.11 14273.00 9561.26 87.23 39.25 6656.28E 5201,85N 0.01 EPOCH 27 ~ FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 MUD RECORD Date Depth Den. Vis PV YP Gels Cake Solids Oil Sand PH Cl 2123101 9650' 9.5 296 38 37 44149157 12 8.89 69% NA NA 30,000 2124101 9662' 9.6 264 37 34 43~46 12 10.5 69% NA NA 30,000 2125101 9662' 9.4+ 181 34 30 38141144 12 9.50 70.5% NA NA 32,000 2126101 9957' 9.2 134 29 25 33138141 12 6.62 72.5% NA NA 36,000 2/27101 10096' 9.3 122 27 21 28131132 12 7.72 74% NA NA 33,000 2128101 10512' 9.2+ 109 27 22 28~32~34 12 7.69 73% NA NA 34,000 311101 10876' 9.3 103 27 24 29~33~34 12 7.73 73% NA NA 33,000 312101 11223' 9.3+ 103 27 22 28~32~34 NA 8.17 73% NA NA 34,000 313101 11489' 9.2 96 26 21 28131133 NA 7.66 75% NA NA 34,000 314101 11567' 9.2 106 25 20 27132135 NA 7.60 73% NA NA 36,000 315101 12046' 9.3 107 27 18 27128133 NA 8.04 73% NA NA 37,000 316101 12391' 9.2 98 25 19 24129134 NA 8.04 73% NA NA 37,000 317101 12521' 9.3 98 28 21 26131136 NA 8.09 73% NA NA 36,000 3/8101 12950' 9.3 90 28 19 25129134 12 8.04 74% NA NA 36,500 319101 12950' 9.3 103 26 19 24130134 12 8.00 74% NA NA 37,000 3110101 12950' 9.4 120 29 19 27134/40 12 8.54 75% NA NA 37,000 3111101 12950' 9.4 t 18 28 22 28133138 12 8.52 74% NA NA 37,000 3112101 12950' 9.4 130 26 22 27132/36 12 8.52 74% NA NA 37,000 3113101 12950' 9.4 130 29 19 28134/39 12 8.52 74% NA NA 37,000 3114101 12950' 9.5 140 24 24 27131137 12 8.52 74% NA NA 36,500 3115101 12950' 9.5 140 24 25 27131137 12 8.54 74% NA NA 36,500 3116101 13037' 9.4 126 26 23 29134/37 12 8.50 74% NA NA 36,500 3117101 13073' 9.4 145 26 24 27133138 12 8.00 74.5% NA NA 36,500 3118101 13195' 9.3 124 25 25 27133138 12 8.54 74% NA NA 36,500 [-'-I EPOOH 28 ~ FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 Date Depth Den. Vis PV YP Gels Cake Solids Oil Sand PH Cl 3119101 13198' 9.4 140 24 21 27135139 12 8.54 74% NA NA 36,500 3120101 13246' 9.3 108 25 19 26135138 12 7.66 75% NA NA 34,000 3121101 13266' 9.3 113 23 18 23~28~34 12 9 75% NA NA 36,000 3122101 13354' 9.3 110 26 20 27~30~36 12 7.61 75% ''NA NA 35,000 3123101 13359' 9.35 159 24 20 26~29~35 12 7.61 75% NA NA 35,000 3124101 13359' 9.3 139 25 19 24~28~36 12 9 75% NA NA 35,000 3125101 13404' 9.3 112 25 20 25131136 12 9 75% NA NA 35,000 3126101 13480' 9.3 108 26 21 25~37~37 12 6.64 74.5% NA NA 35,000 3127101 13515' 9.3 1tl 28 19 24~33~35 12 6.49 75% NA NA 38,000 3128101 13656' 9.3 111 26 18 25134/35~ 12 6.49 75% NA NA 38,000 3129101 13707' 9.3 113 25 20 25~34~36 12 6.48 75.5% NA NA 38,000 3130101 13857' 9.3 107 25 20 25134135 /2 7.54 75% NA NA 36,500 3131101 13858' 9.4 125 25 20 25133135 12 7.57 75% NA NA 36,000 411101 13917' 9.3 122 24 18 22132133 12 9 76% NA NA 36,000 412101 14021' 9.3 103 25 19 24134136 12 9 74% NA NA 32,000 413101 14099' 9.3 104 25 20 23135136 /2 9 75% NA NA 38,000 414101 14189' 9.3 118 26 22 24134/35 12 9 75% NA NA 38,000 4/5101 14273' 9.3 130 26 23 24134137 12 7.47 75% NA NA 38,000 416101 14272' 9.3 140 26 22 25~32~36 12 7.47 75% NA NA 38,000 417101 14273' 9.3 147 26 22 24~33~35 12 7.47 75% NA NA 38,000 4/8101 14273' 9.3 155 27 20 23~33~37 12 7.47 75% NA NA 38,000 419101 14273' 9.3 136 27 20 23133139 12 7.47 75% NA NA 38,000 ~ EPOOH 29 ~ FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 BIT RECORD Bit Grading I I OD L B G O R N U U O E A T E N T L C A U H A E E L A R G E S R R T i E R O C I N N R R H O G C O O A N S H P WW R A U S S R L L E D Bit # Size Make Type SIN Jets Depth Depth Drilled Hours' Ave Ave Ave Ave In Out ft/hr wob rpm psi 1 LK2070 17114" STC MSDSC t8 18 18 12 40' 319' 279' 2 139 2 18 567 2 LK0348 17 114" STC MSDGHOD 18 18 18 12 319' 1987' 1660' 21 79 20 4 1489 2 2 WT A E I NO TD 3 LW5297 12114" STC FGS+C 15 15 18 10 1987' 3759' t772' 34 85 21 35 2003 3 3 WT G E I NO TQ 4 LW5296 12 t14" STC FGS+C 18 18 18 11 3769' 5433' 1674' 55 30 26 53 2466 4 4 FC G E 2 WT PR 5 LW6934 12ti4" STC FGS+C 18 18 18 11 5433' 6334' 901' 55 17 27 47 2531 5 4 WT A E 4 BU PR 6 LR0135 12 114" STC MOSSOD 18 18 18 12 6334' 6535' 201' 39 5 36 40 2750 7 JS3948 8112" STC MA985PX 13 13 13 11 6535' 6535' 0 0 0 (~ 0 3000 NO A D I NO PR 8 640671 8 112" SEC S82FL 16 16 15 6536' 8053' 1517' 12 126 27 40 2780 3 3 LT A E 4 NO PR 9 JS3948 81/2' STC MA985PX 13 13 13 11 8053' 9431' 1378' 54 26 8 55 2482 2 4 WT NT D I NO PR 10 741483 8 112,' SEC S82F 16 16 16 9431 10541' 1110' 47.66 39.5 32.2 35.8 2572 2 4 WT AG E I CT HR S 11 741509 8112,' SEC XS12 16 16 16 10541' 11961 1420 56.7 47.3 30.5 58.2 2882 4 8 WT A E 1/2 LT HR S 12 BP5736 8112" REED EHP51AKPR 16 16 18 11961' 12742 780' 36.18 38.7 39.5 36.9 2799 8 8 BT A 8 112 NA PR [:1 EPOC'H 30 · : FOREST OIL CORPORATION West McArthur River Unit #7 ST #1 t3 ;LW7347 8 112" SMITH 20MFDP 18 18 18 t2742' 13200' 458' 20 41.1 29.6 58.3 2973 2 2 LT M E I WT TD 14 LW3372 8112' SMITH 20MFDGPD 18 18 18 13200' 14009' 809' 38.31 34.1 35.0 48.7 2984 5 7 BT AL F I WT TD L PLUG WELL BACK TOm-> 9850' REDRILL SIDE TRACK ~ 15 LT4853 8112' SMITH MFDSSHR 16 16 16 9850' 10096' 434' 17 14 45.0 14 2461 8 8 WT A E 114 ER PR 16 HF1982 8 112' HYCAL DS75 14 14 15 15 10096' 11484' 1388' 53.6 41.8 22.1 34.7 2433 2 1 WT A X 111 NO PR OG 6 17 741513 8 112" SEC XS 12 16 16 18 11484' 12387' 903' 38.5 36 42.3 36.3 2910 8 8 BT A E I ER PR 18 LW1717 81/2' SMITH 20MFDGDP 18 18 18 12387' 12950' 563' 19.6 28.7 40.1 24.1 3015 I I WT A E I EC LO G 19 LY9626 6.75" SMITH XR20TDG 16 16 16 12950' 13073' 123' 22.2 0 3772 2 2 BT A E 3 EC BH A 20 MG1216 6.75" SMITH XR32TDGPS 18 18 18 13073' 13195' 122' 13.13 9.3 28.1 I 3470 3 5 BT G E I JD HR S 21 MG1214 6.75" SMITH XR32TDGPS 18 18 18 13195' 13246' 61' 6.14 8.3 26.8 1.1 3430 2 2 BT G E I JD DT F 22 MG1211 6.75" SMITH XR32TDGPS 18 18 20 13246' 13354' 108' 20.25 5.33 2~.3 2.9' 3402 0 I WT G 0 I NO DT F 23 MG1206 6.75" SMITH XR32TDGPS 18 18 20 13354' 13359' 5' 0.51 10 25.7 5 3361 4 8 WT A X 2 LT PR 24 MG1206 6.75" SMITH XR32TDGPS 18 18 20 13359' 13480' 12t' 23.1 5.23 32.5 1.9 338~} 4 8 WT A X 2 LT PR 25 MG12t2 6.75" SMITH XR32TDGPS 18 18 20 13480' 13656' 176' 18.4 9.5 26.2 31.4 3313 4 8 BT G E I WT PR 26 G94JE 6.75" HTC EP4983 18 18 18 13656' 13857' 201' 20.7 9.7 41.4 22 3170 2 6 WT G E I CT TQ 27 G93JE 6.75" HTC EP4983 18 18 20 13857' 13917' 60' 4.7 12.8 24.1 40.3 3384 I 2 WT G E i EC DT F 28 E28JE 6.75" HTC STR40DX t8 t8 20 13917' 14099' 182' 20 9. t 24.3 41 3370 3 6 WT G F 1 BT TQ , 29 G92JE 6.75" HTC EP4983 18 18 20 14099' 14276' 177' 20.5 8.63 37.2 18 2714 [:1 EPO' H 31 FOREST OIL CORP WMRU ~rf ST #1 DAILY WELLSITE REPORT EPOCH REPORT FOR MIKE MELLO DATE Apr 09, 2001 TIME 4 AM DEPTH 14273 YESTERDAY 14273 PRESENT OPERATION= PULLING OUT OF HOLE 24 HourFoo~ge 0 CASINGINFORMATION 9.625"@~535'7.625"@12946' DEPTH SURVEY DATA INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C.1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C.5) HYDROCARBON SHOWS INTERVAL LITHOLOGY PRESENT LITHOLOGY 136 7.47 DALLY ACTIVITY SUMMARY SIN INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED HIGH LOW AVERAGE CURRENT AVG o.0 @ 0 o @ o 0 fi/hr 0 @ 0 0 @ 0 0 amps 0 @ 0 0 @ 0 0 Klbs 0 @ 0 0 @ 0 0 RPM 0 @ 0 0 @ 0 0 psi DEPTH: PV 27 YP 20 FL 5.8 Gels 23/33/36 CL- 38000 SD OIL 75% MBL pH Ca+ CCI LITHOLOGY/REMARKS HIGH LOW AVERAGE 0 @ 0 0 @ 0 0 TRIP GAS= 0 @ 0 0 @ 0 0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH= 0 @ 0 0 @ 0 0 AVG= 0 @ 0 0 @ 0 0 CURRENT 0 @ 0 0 @ 0 0 CURRENTBACKGROUND/AVG o @ o o @ o o GAS DESCRIPTION RUN IN HOLE WITH 4.5" SLOTTED LINER AND HANGER. ClRC AND cOND MUD AT 12948 FEET. CONTINUE TO RUN IN HOLE, TAGGED BO'I-rOM. SET HMC HANGER. PULLING OUT OF HOLE, LAYING DOWN DRILL PIPE, SUCKING OIL BASE MUD FROM PIPE. Epoch Personel On Board= 2 Daily Cost 2850 Report by: BARRY VVRIGHT FOREST OIL WMRU fl7 ST #1 REPORT FOR MIKE MELLO DATE Apr 05, 2001 TIME 4 AM DAILY WELLSITE REPORT DEPTH 14269 YESTERDAY 14172 24 Hour Footage 97 CASING INFORMATION 9.625"(~535' 7.625"@12950' DEPTH 14110.94 14139,89 14170.30 14203.09 14273.00 SIN G92JE JETS 2X18,1X20 28.8 15543 2O 62 3560 118 PV 9.0 SD HIGH 4 o @ SURVEY DATA BIT INFORMATION NO. SIZE TYPE 28 6.750 EP4983 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,3 VIS FC 12 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS METHANE(C-I) 503 @ ETHANE(C-2) 72 @ PROPANE(C-3) 62 BUTANE(C-4) 130 @ PENTANE(C-5) 44 @ HYDROCARBON SHOWS INTERVAL INCLINATION 88.21 87.04 86.98 87.23 87.23 INTERVAL IN OUT 14099 14273 AZIMUTH 41.17 39.76 38.98 39.25 39.25 FOOTAGE 174 HIGH LOW @ 14219 4.5 @ 14259 @ 14243 6278 @ 14182 @ 14220 14 @ 14267 @ 14177 27 @ 14182 @ 14197 2669 @ 14182 DEPTH: 14189 26 YP 22 FL 6.0 OIL 75% MBL EPOCH PRESENT OPERATION= OUT OF HOLE LOW AVERAGE 14233 2 @ 14265 3.3 14269 0 @ 14269 0.0 CH ROMATOG RAP HY(ppm) 14230 87 @ 14269 265.8 14180 23 @ 14269 39.9 14172 16 @ 14241 30.4 14221 I @ 14241 22.6 14230 1 @ 14254 8.6 NO SHOWS LITH OLOGY/REMARKS VERTICAL DEPTH 9553.44 9554.64 9556.22 9557.88 9561.26 CONDITION REASON HOURS T/B/C PULLED 20,5 AVERAGE CURRENT AVG 11.5 10.1 fi/hr 14202.3 13644.8 amps 18.8 20.5 Klbs 54.7 50 RPM 3458,3 3429 psi Gels 24/34135 pH CL- 38000 Ca+ CCI TRIP GAS= WIPER GAS= S U RVEY= CONNECTION GAS HIGH= AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 0 GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS CLAYSTONE, TUFF PRESENT LITHOLOGY CONGLOMERATIC SAND DAILY ACTIVITY SUMMARY DRILLED 14172 TO 14273 FEET ('I'D). POH TO SHOE. MONITOR WELL, DROP DART, PUMP PILL. PULLED OUT OF HOLE. Epoch Personel On Board= 4 Daily Cost 2850 Report by: BARRY WRIGHT FOREST OIL CORP DAILY WELLSITE REPORT WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE Apr 03, 2001 DEPTH 14099 TIME 04:02:56 YESTERDAY 14025 24 Hour Footage 74 llll CASING INFORMATION 9.625"@6535' 7.825"@12950 DEPTH SURVEY DATA 13859.68 13888.95 EPOCH PRESENT OPERATION= PULLING OUT OF HOLE INCLINATION 88.15 88.89 AZIMUTH VERTICAL DEPTH 41.03 9545.40 40.93 9546.15 BIT INFORMATION NO. SIZE TYPE 27 6.750 STR40DX 28 6.75 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC 12 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I-rlNG GAS 103 9.0 INTERVAL SIN JETS IN OUT FOOTAGE E28JE 2X18;lX20 13917 14099 182 14099 HIGH LOW 25.4 @ 14041 4.2 @ 14082 15834 @ 14042 -75 @ 14050 73 @ 14054 7 @ 14093 64 @ 14034 1 @ 14098 3518 @ 14053 3004 @ 14040 DEPTH: 14021 PV 25 YP 19 FL 6.2 SD OIL 74% MBL HIGH LOW AVERAGE @ 14027 7 @ 14099 10.3 @ 14099 0 @ 14099 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 769 @ 14027 45 @ 14095 ETHANE(C-2) 76 @ 14033 16 @ 14095 PROPANE(C-3) 85 @ 14070 11 @ 14099 BUTANE(C-4) 49 @ 14035 I @ 14090 PENTANE(C-5) 9 @ 14034 I @ 14099 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS 300.9 43.7 40.9 28.3 1.3 HOURS 20.3 AVERAGE 12.4 10943.0 24.3 41.0 3369.7 , , Gels 24/34/36 pH GAS LITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS SILTSTONE/CLAYSTONE, TUFF PRESENT LITHOLOGY SAND 80%, TUFFACEOUS SILTSTONE 20% DAILY ACTIVITY SUMMARY DRILLED 14025 TO 14099 FEET. PUMPED HI VIS SWEEP. PULLING OUT OF HOLE. CONDITION T/B/C CURRENT AVG 7.2 36.3 50.3 0 3233 CL. 32000 Ca+ REASON PULLED DTF fi/hr amps Klbs RPM psi CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 5.7 CURRENT 6.0 CURRENT BACKGROUND/AVG 6.3 DESCRIPTION Epoch Personel On Board= 4 Daily Cost 2850 Report by: BARRY WRIGHT FOREST OIL CORP WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE Apr 02, 2001 TIME 04:02:56 DAILY WELLSITE REPORT DEPTH 14025 YESTERDAY 13917 24 Hour Footage 108 CASING INFORMATION 9.625" @ 6535' 7.625" @ 12950' DEPTH 13859.68 13888.95 SURVEY DATA INCLINATION 88.15 88.89 AZIMUTH 41.03 40.93 EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH 9545.40 9546.15 BIT INFORMATION NO. SIZE TYPE SIN 26 6.750 EP4983 G93JE 27 6.750 STR40DX E28JE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 v~s 103 PV FC /2 SOL 7.77 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS 11 CUTTING GAS 0 INTERVAL JETS IN OUT 2X18;1X20 13857 13917 2X18;lX20 13917 HIGH LOW 137.1 @ 13926 3.4 @ 15738 @ 13995 -88 49 @ 13958 5 65 @ 13921 1 3547 @ 13993 2542 DEPTH: 14021 25 YP 19 FL OIL 74% MBL FOOTAGE 6O 13956 13943 13919 13963 13943 HOURS 4.7 AVERAGE 20.1 9949.5 24.1 40.3 3383.9 6.2 HIGH LOW AVERAGE @ 14000 5 @ 13922 8.2 @ 14000 0 @ 14000 0.0 CHROMATOGRAPHY(ppm) Gels pH 24/34/36 CONDITION T/B/C CURRENT AVG 15.4 15357.2 18.9 60 3514 CL- 32000 Ca+ REASON PULLED DTF IN HOLE METHANE(C-I) 535 @ 14000 60 @ 13958 212.5 ETHANE(C-2) 65 @ 13999 14 @ 13955 36.3 PROPANE(C-3) 52 @ 14000 7 @ 13947 25.0 BUTANE(C-4) 50 @ 13917 1 @ 13947 16.9 PENTANE(C-5) 25 @ 14000 I @ 13991 1.5 HYDROCARBON SHOWS INTERVAL NO SHOWS LITHOLOGY/REMARKS ft/hr amps Klbs RPM psi CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 8.2 CURRENT 11.91 CURRENT BACKGROUND/AVG 11.22 GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS SILTSTONE, TUFF PRESENT LITHOLOGY SAND (70%), TUFFACEOUS SlLTSTONE (20%), TUFF (10%) DAILY ACTIVITY SUMMARY PULLED OUT OF HOLE. RAN IN HOLE, TESTING MWD TOOL - OKAY. DRILLED 13917 TO 14025 FEET. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE Apdl 1, 2001 TIME 04:12:17 DAILY WELLSITE REPORT DEPTH 13917 YESTERDAY 13857 24 Hour Footage 60 INCLINA'RON CASING INFORMATION 9.625" @ 6535' 7.625" @ 12950' DEPTH SURVEY DATA EPOCH PRESENT OPERATION= PULLING OUT OF HOLE AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE SIN 25 6.750 EP4983 G93JE DRILLING PARAMETERS RATE OF PENETRATION 61.1 SURFACE TORQUE 13243 WEIGHT ON BIT 20 ROTARY RPM 65 PUMP PRESSURE 3469 DRILLING MUD REPORT MW 9.3 VIS 122 PV FC /2 SOL 9.0 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH DITCH GAS 9 CUTTING GAS 0 METHANE(C.1) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL JETS 2X18;1X20 INTERVAL IN OUT 13857 HIGH @ 13861 4.2 @ 13873 1874 @ 13877 11 @ 13873 9 @ 13875 3017 DEPTH: 13917 24 YP 18 OIL 76% FOOTAGE 60' LOW @ 13860 @ 13872 @ 13859 @ 13872 @ 13872 FL 6.4 MBL CONDITION REASON HOURS T/B/C PULLED 4.7 DTF AVERAGE AVERAGE CURRENT AVG 15.4 15,2 It/hr 12004.9 12097.7 amps 17.8 17.5 KIbs 54.6 55 RPM 3412.8 3406 psi Gels 22/32/33 CL- pH Ca+ 36000 CCI LOW 13905 4 @ 13858 6.9 TRIP GAS= 13917 0 @ 13917 0.0 WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 687 @ 13905 82 @ 13898 363.1 CONNECTION GAS HIGH= 84 @ 13869 19 @ 13872 46.0 AVG= 6.9 167 @ 13869 10 @ 13877 35.3 CURRENT 6.21 129 @ 13876 4 @ 13890 26.4 CURRENT BACKGROUND/AVG 6.5 18 @ 13880 1 @ 13891 3.0 NO SHOWS LITHOLOGY/REMARKS LITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS SILTSONE, TUFF PRESENT LITHOLOGY SAND (60%), CONGLOMERATIC SAND (20%), TUFFACEOUS SILTSTONE (20%) GAS DESCRIPTION SLIPPED AND CUT DRILL LINE. RETEST MWD TOOL AT 7 5/8" SHOE.ORIENT HIGH SIDE AND RAN IN HOLE, REAMING 13749 FEET TO Bo'FrOM. TAGGED BO'FI'OM AND PUMPED SURVEY, MWD FAILURE. DRILLED 13871 TO 13909 FEET. A'I-I'EMPTED MWD SURVEY- FAILED. DRILLED 13909 TO 13917 FEET. MADE MAD PASS FROM 13917 TO 13225 FEET. PULLED INTO 7 5~8" SHOE. PUMPED POS DARTAND DRY JOB. PULLING OUT OF HOLE. DALLY ACTIVITY SUMMARY Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP V~MRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 31, 2001 TIME 04:02:11 DALLY WELLSITE REPORT EPOCH DEPTH 13857 YESTERDAY 13857 PRESENT OPERATION= RUNNING IN HOLE 24 Hour Footage 0 CASING INFORMATION 9.625" @ 6535' 7.625" @ 12950' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH ,, BIT INFORMATION NO. SIZE TYPE SIN 25 6.750 EP4983 G94JE 26 6.750 EP4983 G93JE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS 125 FC 2/ SOL 7.57 MVVD SUMMARY INTERVAL TO TOOLS JETS 3Xl 8 2X18;1X20 HIGH lO.7 @ 12418 19 @ 54 @ 316o @ INTERVAL IN 13656 13857 OUT 13857 FOOTAGE 201 LOW 13857 10.7 @ 13857 13857 12418 @ 13857 13857 19 @ 13857 13857 54 @ 13857 13857 3160 @ 13857 DEPTH: 13857 PV 25 YP 2O SD OIL 74.5% ,, GAS SUMMARY(units) HIGH LOW DITCH GAS 6 @ 13857 6 @ 13857 CUTTING GAS @ @ CHROMATOGRAPHY(ppi) FL MBL METHANE(C-I) 175 @ 13857 175 @ 13857 ETHANE(C.2) 34 @ 13857 34 @ 13857 PROPANE(C-3) 31 @ 13857 31 @ 13857 BUTAN E(C-4) 19 @ 13857 19 @ 13857 PENTANE(C-5) 0 @ 13857 0 @ 13857 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY 6.0 CONDITION REASON HOURS T/B/C PULLED 20.7 HRS AVERAGE CURRENT AVG 1 .$ 10.7 fi/hr 1.$ 12418.1 amps 1.$ 19.9 Klbs 1 .$ 54 RPM 1 .$ 3160 psi Gels 25/33~35 CL- 36000 pH Ca+ CCI AVERAGE 6 GAS TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 6 CURRENT 6.7 CURRENT BACKGROUND/AVG 6.8 DESCRIPTION PRESENT LITHOLOGY SAND (70%), CONGLOMERATIC SAND (20%), TUFF (10%) DAILY ACTIVITY SUMMARY PULLED OU OF HOLE. PICKED UP MWD AND AVl TOOL, PROBLEM WITH LWD TOOL. RUNNING IN HOLE TO SHOE. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 30, 2001 TIME 04:04:42 DAILY WELLSITE REPORT DEPTH 13857 YESTERDAY 13725 24 Hour Footage 132 CASING INFORMATION 9.625" @ 6535' 7.625" @ 12950' DEPTH 13703,25 SURVEY DATA 13733.54 13770.90 13806.13 INCLINATION 85.90 84.97 84.75 86.64 EPOCH BIT INFORMATION NO. SIZE TYPE 25 6.750 EP4983 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC /2 SOL TO MWD SUMMARY INTERVAL TOOLS SIN JETS G94JE 3X18 134.8 14O63 79 63 3275 I O7 PV 7.54 SD GAS SUMMARY(units) DITCH GAS CUTTING GAS PRESENT OPERATION= PULLING OUT OF HOLE HIGH VERTICAL DEPTH 9534.4 9536.8 9540.2 9542.8 CONDITION T/B/C INTERVAL IN OUT FOOTAGE 13656 13857 201 HIGH LOW @ 13792 5.6 @ 13818 @ 13742 -151 @ 13800 @ 13814 12 @ 13762 @ 13743 I @ 13845 @ 13838 2641 @ 13725 DEPTH: 13857 25 YP 20 FL 6.0 OIL 75% MBL AZIMUTH 41.08 40.61 40.46 40,43 HOURS 20.7 AVERAGE 18.0 5282.1 41.4 22.0 3170.4 Gels 25~34~35 pH LOW AVERAGE 13771 4 @ 13762 6.0 CHROMATOGRAPHY(ppm) 13769 59 @ 13762 190.2 13769 15 @ 13762 32.9 '13810 11 @ 13789 29.3 13825 1 @ 13839 13.3 13773 I @ 13841 1.9 REASON PULLED IN HOLE CURRENT AVG 10.7 fi/hr 12418.1 amps 19.9 Klbs 54 RPM 3160 psi CL- Ca+ 36500 CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 6 CURRENT 6.7 CURRENT BACKGROUND/AVG 6.8 METHANE(C-I) 518 @ ETHANE(C-2) 65 PROPANE(C-3) 72 BUTANE(C-4) 79 @ PENTANE(C-5) 21 HYDROCARBON SHOWS INTERVAL NO SHOWS LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, TUFF, CONGLOMERATIC SAND, TUFFACEOUS SILTSTONE, TUFFACEoUs CLAY PRESENT LITHOLOGY SAND (70%), CONGLOMERATIC SAND (20%), TUFF (10%) DALLY ACTIVITY SUMMARY DRILLED 13725 TO 13857 FEET. PUMPED HI VIS SWEEP. PULLING OUT OF HOLE FOR NEW BIT. Epoch Personel On Board= 4 Report by: LOWELL PRICE Daily Cost $2850 FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 29, 2001 TIME 04:03:51 DAILY WELLSITE REPORT DEPTH 13725 YESTERDAY 13656 24 Hour F~ge 79 CASING INFORMATION 9.625"@6535' 7.625"@12950' DEPTH 13583.28 SURVEY DATA 13601.35 13640.75 13670.65 BIT INFORMATION NO. SIZE TYPE S/N 24 6.750 XR32TDGPS MG1212 25 6.750 EP4983 G94JE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS EPOCH METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL PRESENT OPERATION= DRILLING INCLINATION AZIMUTH VERTICAL DEPTH 85.46 40.97 9526.58 85.95 41.17 9527.94 86.76 41.14 9530.44 86.36 40.67 9532.23 INTERVAL CONDITION REASON JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2X18;1X20 13480 13656 176 18.4 NB 3X18 13656 79 6,3 IN HOLE HIGH LOW AVERAGE CURRENT AVG 32.6 @ 13680 4,9 @ 13656 15.9 11.6 ~hr 13138 @ 13710 8663 @ 13688 12071,1 13138.4 amps 21 @ 13710 15 @ 13688 19.4 21.8 Klbs 63 @ 13694 39 @ 13688 56.4 62 RPM 3334 @ 13656 3188 @ 13706 3307.0 3198 psi DEPTH: 13707 113 PV 25 YP 20 FL 5.8 Gels 25/34/36 CL- 6.48 SD OIL 75.5% MBL pH Ca+ 38000 CCI HIGH LOW AVERAGE 7 @ 13682 3 @ 13656 5,7 TRIP GAS= @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 329 @ 13688 82 @ 13656 246,9 CONNECTION GAS HIGH= 53 @ 13688 29 @ 13659 42,4 AVG= 5.7 37 @ 13705 10 @ 13656 25.2 CURRENT 6.45 27 @ 13709 2 @ 13657 13.6 CURRENT BACKGROUND/AVG 6.41 8 @ 13660 1 @ 13657 0.6 NO SHOWS LITHOLOGY/REMARKS LITHOLOGY SAND, TUFF, TUFFACEOUS SILTSTONE, CONGLOMERATIC SAND PRESENT LITHOLOGY SAND (90%), TUFF (10%) DAILY ACTIVITY SUMMARY GAS DESCRIPTION PULLED OUT OF HOLE FOR NEW BIT.TEST BOP'S. RUN IN HOLE. WASHED AND REAMED 13421 TO 13425 FEET. REAMED BOTTOM 56 FEET. DRILLED 13656 TO 13725 FEET. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 28, 2001 TIME 04:04:25 DALLY WELLSITE REPORT DEPTH 13656 YESTERDAY 13515 24 Hour Footage 141 CASING INFORMATION 9.625" (~ 6535' 7.625" @ 12950' DEPTH 13498.82 13515.52 13532.58 13546.77 13566.47 SURVEY DATA BIT INFORMATION NO. SIZE TYPE SIN 24 6.750 XR32TDGPS MG1212 DRILLING PARAMETERS RATE OF PENETRATION 82.3 SURFACE TORQUE 12605 WEIGHT ON BIT 60 ROTARY RPM 64 PUMP PRESSURE 3403 DRILLING MUD REPORT MW 9.3 VIS 111 PV FC /2 SOL 6.49 SD MVVD SUMMARY INTERVAL TO TOOLS JETS 2X18;1X20 HIGH @ 13633 (~ 13629 @ 13543 @ 13643 @ 13600 DEPTH: 13656 26 YP OIL EPOCH INCLINATION 89.63 87.57 85.53 85.13 85.31 INTERVAL IN 13480 PRESENT OPERATION= PULLING OUT OF HOLE 4.5 -1433 5 1 2570 18 75% OUT LOW FL MBL GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS S @ 13575 2 @ 13545 4.0 CUTTING GAS @ CHROMATOGRAPHY(ppm) METHANE(C-I) 413 @ 13598 60 @ 13528 176.4 ETHANE(C-2) 61 @ 13636 6 @ 13528 24.3 PROPANE(C-3) 54 @ 13636 2 @ 13649 13.3 BUTANE(C-4) 27 @ 13630 2 @ 13600 3.2 PENTANE(C-5) 10 @ 13603 I @ 13592 0.4 "Hy~)RocARBON' SHOWS '" NO SHOWS" ,.TERV^L UTHO OGY REMAR S LITHOLOGY SAND, TUFFACEOUS SILTSTONE, TUFF, CONGLOMERATIC'SAND PRESENT LITHOLOGY SAND, TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY AZIMUTH 41.78 41.80 41.46 41.17 40.85 FOOTAGE 176 VERTICAL DEPTH 9521.00 9523.89 9525.00 9526.16 9527.8O CONDITION REASON HOURS T/B/C PULLED 18.4 IN HOLE AVERAGE CURRENT AVG 13648 15.2 4.6 ft/hr 13515 7659.0 11804.7 amps 13644 26.2 21.8 Klbs 13522 31.4 56 RPM 13546 3313.4 3329 psi 5.8 Gels 25/34/35 CL- 38000 pH Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 4 CURRENT 4.47 CURRENT BACKGROUND/AVG 4.47 GAS DESCRIPTION REPAIRED TOP DRIVE. DRILLED 13515 TO 13643 FEET. PUMPED HI VIS SWEEP. DRILLED 13643 TO 13658 FEET. PULLING OUT OF HOLE FOR NEW BIT. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 27, 2001 TIME 04:16:18 DAILY WELLSITE REPORT DEPTH 13515 YESTERDAY 13480 24 Hour Footage 35 CASING INFORMATION 9.625" @ 6535' 7.625" (~ 12950' DEPTH 13411.84 SURVEY DATA 13428.68 13441.61 13459.81 INCLINATION 96.67 95.00 94.38 93.30 BIT INFORMATION NO. SIZE TYPE SIN 24 6.750 XR32TDGPS MG1212 ,,, DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS 111 PV FC 12 SOL 6.49 SD INTERVAL JETS IN OUT FOOTAGE 2X18;1X20 13480 35 90.9 2026 52 8 3421 HIGH LOW @ 13512 5.4 (~ 13502 @ 13488 -1433 @ 13515 @ 13499 11 @ 13502 @ 13512 1 @ 13510 @ 13488 3010 @ 13515 DEPTH: 13515 28 YP 19 FL 5.8 OIL 75% MBL MVVD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH 4 @ METHANE(C-I) 87 @ 13515 ETHANE(C-2) 11 @ 13500 PROPANE(C-3) 8 @ 13490 BUTANE(C-4) 0 @ 13515 PENTANE(C-5) 0 @ 13515 i i ii i i HYDROCARBON SHOWS INTERVAL LITHOLOGY SAND, TUFFACEOUS SILTSTONE, TUFF PRESENT LITHOLOGY SAND (80%), TUFFACEOUS SILTSTONE (20%) DAILY ACTIVITY SUMMARY LOW AVERAGE 13515 2 @ 13492 3.6 CHROMATOGRAPHY(ppm) 24 @ 13481 44,7 3 @ 13481 6.9 1 @ 13510 2.2 0 @ 13515 0.0 0 @ 13515 0.0 NO SHOWS LITHOLOGY/REMARKS EPOCH PRESENT OPERATION= DRILLING AZIMUTH VERTICAL DEPTH 43.31 9526.12 43.41 9524.41 42.83 9523.35 42.55 9522.13 CONDITION REASON HOURS T/B/C PULLED 4.75 (ON BOTTOM) IN HOLE AVERAGE CURRENT AVG 26.1 23.8 fi/hr 602.4 -1433.4 amps 32.7 28.9 Klbs 1.7 0 RPM 3173.6 3010 psi Gels 24/33/35 pH CL- 38000 Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 3.6 CURRENT 4.47 CURRENT BACKGROUND/AVG 4.1 GAS DESCRIPTION PULLED OUT OF HOLE FOR NEW BIT. ADD THRUSTER MVVD TOOL TO BHA. TRIPPED INTO HOLE. DRILLED (SLIDE) 13480 TO 13515 FEET. WORKING ON TOP DRIVE. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP DALLY WELLSITE REPORT WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 26, 2001 DEPTH 13480 TIME 04:02:06 YESTERDAY 13400 24 Hour Footage 80 CASING INFORMATION 9.625" @ 6535' 7.625" @ 12950' DEPTH 13264.30 13289.83 SURVEY DATA 13318.32 13352.20 13384.67 BIT INFORMATION NO. SIZE TYPE SIN JETS 23 6.750 XR32TDGPS MG1206 2X18;1X20 EPOCH PRESENT OPERATION= PULLING OUT OF HOLE FOR NEW BIT INCLINATION 92.65 94.91 96.67 97.94 96.29 INTERVAL IN OUT 13354 13480 FOOTAGE 126 AZIMUTH VERTICAL DEPTH 50.05 9542.04 49.10 9540.36 46.44 9537.49 44.28 9533.18 43.48 9529.16 CONDITION HOURS T/B/C 23.1 (ON aOTTOM) REASON PULLED IN HOLE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS 108 PV 6.64 SD GAS SUMMARY(units) HIGH DITCH GAS 4 CUTTING GAS 0 METHANE(C.1) 139 @ ETHANE(C-2) 36 @ PROPANE(C-3) 11 BUTANE(C-4) 0 PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL 57.7 8537 56 7 3531 HIGH LOW @ 13423 2,7 @ 13478 @ 13415 -24 @ 13444 @ 13463 8 @ 13422 @ 13400 1 @ 13473 @ 13438 3004 @ 13418 DEPTH: 13480 26 YP 21 FL 5.6 OIL 74.5% MBL 13412 13435 13425 13480 13480 LOW AVERAGE 13455 I @ 13402 3,1 13480 0 @ 13480 0.0 CHROMATOGRAPHY(ppm) 26 @ 13465 87.0 4 @ 13479 16.3 1 @ 13479 4,1 0 @ 13480 0.0 0 @ 1348O 0.0 NO SHOWS LITHOLOGY/REMARKS LITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS SILTSTONE, TUFF PRESENT LITHOLOGY SAND (60%), TUFFACEOUS SILTSTONE (40%) DAILY ACTIVITY SUMMARY AVERAGE CURRENT AVG 10.6 13,2 fi/hr 2322.2 1265.8 amps 32.5 25.6 Klbs 1.9 2 RPM 3383.4 3394 psi Gels 25/37/37 CL- pH Ca+ 35000 CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 3.1 CURRENT 2.98 CURRENT BACKGROUN D/AVG 3.17 GAS DESCRIPTION DRILLED (SLIDE) 13400 TO 13480 FEET. CIRCULATED BO'I-I-OMS UP. PUULED INTO 7 5/8" SHOE. PUMPED POS DART. PUMPED DRY JOB. PULLING OUT OF HOLE FOR NEW BIT. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 25, 2001 TIME 04:13:09 DALLY WELLSITE REPORT DEPTH 13400 YESTERDAY 13359 24 Hour Footage 41 CASING INFORMATION 9.625" @ 6535' 7.625"@ 12950 DEPTH INCLINATION INTERVAL SIN JETS IN MG1206 2X18;lX20 13354 HIGH 37.0 @ 13360 2.4 9879 @ 13359 14 40 @ 13380 2 18 @ 13359 1 3645 @ 13359 2828 DEPTH: 13404 PV 25 YP 20 SD OIL 75% 112 9.0 SURVEY DATA BIT INFORMATION NO. SIZE TYPE 23 8.750 XR32TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLINO MUD REPORT MW 9.3 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS HIGH 2 @ o METHANE(C-I) 120 @ ETHANE(C-2) 14 @ PROPANE(C-3) 0 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL OUT LOW FL MBL AZIMUTH FOOTAGE 13373 13362 13362 13375 13384 6.8 LOW AVERAGE 13392 0 @ 13368 1.1 13400 0 @ 13400 0.0 CHROMATOGRAPHY(ppm) 13391 10 @ 13380 45.8 13400 1 @ 13393 3.1 13400 0 @ 13400 0.0 13400 0 @ 13400 0.0 13400 0 @ 13400 0.0 NO SHOWS LITHOLOGY/REMARKS EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH CONDITION HOURS T/B/C AVERAGE 10.4 4487.8 23.4 4.2 3492.4 Gels 25/31/36 pH CURRENT AVG 20.3 8273.2 24.3 7 3384 CL- Ca+ REASON PULLED IN HOLE fi/hr amps Klbs RPM psi 35000 CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 1.1 CURRENT 1.99 CURRENT BACKGROUND/AVG 1.88 GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS SILTSTONE, TUFF, TUFFACEOUS CLAY. PRESENT LITHOLOGY SAND (60%), TUFFACEOUS SILTSTONE (30%), TUFF (10%). DAILY ACTIVITY SUMMARY PULLED OUT OF HOLE. LAID DOWN LWD TOOL. RAN IN HOLE WITH BHA, TESTED MWD - OKAY. RAN IN HOLE, TEST MWD AT 3500 FEET - OKAY. SERVICED RIG. RAN IN HOLE, TESTED MWD AT 7 5/8" SHOE - OKAY. RAN IN HOLE TO TD. DRILLED 13359 TO 13400 FEET. Epoch Personei On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE MARCH 24, 2001 TIME 04:23:56 DAILY WELLSITE REPORT DEPTH 13359 YESTERDAY 13359 24 Hour Footage 0 INCLINATION CASING INFORMATION 9.625"(~ 6535' 7.625"@ 12950' DEPTH SURVEY DATA TYPE XR32TDGPS 139 7.61 SIN JETS MG1206 2X18;1X20 HIGH 5.7 @ 13355 0 (~ 13355 11 @ 13355 0 @ 13355 0 @ 13355 DEPTH: 13359 PV 25 YP SD OIL HIGH INTERVAL IN. 13359 BIT INFORMATION NO. SIZE 23 6.750 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS EPOCH PRESENT OPERATION= PULLING OUT OF HOLE METHANE(C-I) 48 @ ETHANE(C-2) 1 @ PROPANE(C-3) 0 BUTANE(C--4) 0 PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL AZIMUTH VERTICAL DEPTH CONDITION REASON HOURS T/B/C PULLED 0.51 IN HOLE OUT FOOTAGE LOW 5.7 ~ 13355 0 @ 13355 11 @ 13355 0 @ 13355 0 @ 13355 19 FL 6.8 Gels 75% MBL pH LOW AVERAGE 13355 1 @ 13355 1 CHROMATOGRAPHY(ppm) 13355 48 @ 13355 1.$ 13355 1 @ 13355 1,$ 13355 0 (~ 13355 -1.$ 13355 0 @ 13355 -1.$ 13355 0 @ 13355 -1.$ NO SHOWS LITHOLOGWREMARKS AVERAGE 5.7 24/28/36 GAS CURRENT AVG 5.7 11.8 CL- 35000 Ca+ fi/hr amps Klbs RPM psi CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 1.24 CURRENT 1.74 CURRENT BACKGROUND/AVG 1.59 LITHOLOGY SAND, CONGLOMiRATIC sAND, TUFFACEOUS CLAY, TUFF, TUFFACEOUS SILTSTONE. PRESENT LITHOLOGY SAND, TUFFACEOUS SILTSTONE, TUFF DAILY ACTIVITY PULLED OUT OF HOLE. CHECKED AND SERVICED MWD. RAN IN HOLE WITH 3.5" DRILL PIPE, TEST MWD. ~:;~N IN HOLE WITH 5" SUMMARY DRILL PIPE, TESTING MWD EVERY TEN STANDS, NOISE INCREASING WITH DEPTH. ATTEMPTED SURVEY AT 7 5/8" SHOE - ' FAILED. DROPPED POS DARTAND PUMPED DRY JOB. PULLING OUT OF HOLE. DESCRIPTION Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DATE MARCH 23, 2000 TIME 04:05:52 DAILY WELLSITE REPORT DEPTH 13359 YESTERDAY 13354 24 Hour Footage 5 CASING INFORMATION 9.625"@ 6535' 7.625" @ 12950' DEPTH SURVEY DATA INCLINATION EPOCH PRESENT OPERATION= PULLING OUT OF HOLE AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE S/N 22 6.750 XR32TDGPS MG1211 23 6.750 XR32TDGPS MG1206 INTERVAL JETS IN OUT 2X18;1X20 13256 13354 2X18;1X20 13354 13359 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 98 20.25 NB 5 0.51 IN HOLE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.35 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS 159 PV 7.61 SD GAS SUMMARY(units) HIGH DITCH GAS 1 @ CU'i-rlNG GAS METHANE(C-I) 64 @ ETHANE(C-2) 1 PROPANE(C-3) 0 BUTANE(C-4) 0 @ PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL 6.9 8429 13 5 3361 HIGH LOW (~ 13354 5.7 @ 13355 (~ 13354 8429 (~ 13354 @ 13354 11 @ 13355 @ 13354 5 @ 13354 @ 13354 3361 @ 13354 DEPTH: 13359 24 YP 2O FL 6.6 OIL 75% MBL AVERAGE CURRENT AVG 12.6 5.7 fi/hr 8429.6 amps 25.7 11.8 Klbs 5.0 RPM 3361.0 psi Gels 26/29135 CL- 35000 pH Ca+ LOW AVERAGE 13354 1 @ 13355 1 CHROMATOGRAPHY(ppm) 13354 48 @ 13355 112.0 13354 1 @ 13355 2.0 13355 0 @ 13355 0.0 13355 0 @ 13355 0.0 13355 0 @ 13355 0.0 NO SHOWS LITHOLOGY/REMARKS CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 1 CURRENT 1.74 CURRENT BACKGROUND/AVG 1.59 GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS CLAY, TUFF, TUFFACEOUS SILTSTONE PRESENT LITHOLOGY SAND, TUFFACEOUS SILTSTONE, TUFF DAILY ACTIVITY SUMMARY PULLED OUT OF HOLE, PICKED UP LWD TOOLS, RAN IN HOLE TO SHOE, SLIPPED AND CUT DRILL LINE, CONTINUED RUNNING IN HOLE, MADE MAD PASS THROUGH UNLOGGED SECTION OF HOLE BELOW7 5/8" SHOE, DRILLED 13354 TO 13359 FEET, UNABLE TO GET FACE SIGNAL FROM MWD TOOL, PULLING OUT OF HOLE. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 22, 2001 TIME 04:29:33 DAILY WELLSITE REPORT DEPTH 13354 YESTERDAY 13275 24 Hour Footage 79 EPOCH CASING INFORMATION 9.625" @ 6535' 7.625" @ 12950' DEPTH 13227.05 SURVEY DATA 13264.30 13289.83 PRESENT OPERATION= PULLING OUT OF HOLE INCLINATION 90.25 92.65 94.91 AZIMUTH VERTICAL DEPTH 53.52 9543.01 50.05 9542.07 49.10 9540.39 BIT INFORMATION NO. SIZE 22 6.750 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS i GAS SUMMARY(units) DITCH GAS CU'H'ING GAS TYPE XR32TDGPS 110 7.61 INTERVAL SIN JETS IN MG1211 2X18;1X20 13256 HIGH 119.6 @ 13326 3.4 9005 @ 13303 -35 57 @ 13334 7 10 @ 13339 1 3668 @ 13299 2351 DEPTH: 13354 PV 26 YP 20 SD OIL ,75% HIGH OUT 13354 LOW FL MBL METHANE(C-I) 10043 ETHANE(C-2) 10066 PROPANE(C-3) 10089 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL LOW 13287 0 @ 13348 CHROMATOGRAPHY(ppm) 13351 27 @ 13351 I @ 13351 1 @ 13354 0 @ 13354 0 @ NO SHOWS CONDITION REASON FOOTAGE HOURS T/B/C PULLED 98 20.25 IN HOLE AVERAGE CURRENTAVG 13353 15.7 6,9 ~hr 13345 4360.6 8429.6 amps 13311 24.3 13.9 Klbs 13350 2.9 5 RPM 13291 3402.3 3361 psi 6.6 Gels 27/30136 CL-' 35000 pH Ca+ CCI AVERAGE 1.8 TRIP GAS= WIPER GAS= SURVEY= 13338 563.2 CONNECTION GAS HIGH= 13350 510.7 AVG= 1.8 13347 511.4 CURRENT 1.74 13354 0.0 CURRENT BACKGROUND/AVG 1.49 13354 0.0 LITHOLOGY/REMARKS GAS DESCRIPTION I-ITHOLOGY SAND, CONGLOMERATIC SAND, TUFFACEOUS CLAY, TUFF, TUFFACEOUS SILTSTONE PRESENT LITHOLOGY SAND, TUFFACEOUS SILTSTONE, TUFF DAILY ACTIVITY SUMMARY DRILLED 13256 TO 13354 FEET, CIRCULATED, PULLED UP TO 7 5/8" SHOE AND PUMPED DRY JOB, PULLING OUT OF HOLE FOR NEW BIT. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP V~dRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 21, 2001 TIME 04:18:22 DAILY WELLSITE REPORT DEPTH 13275 YESTERDAY 13246 24 Hour Footage 29 iii CASING INFORMATION 9.625"@ 6535' 7.625"@ 12950' DEPTH SURVEY DATA INCLINATION BIT INFORMATION NO. SIZE TYPE 21 6.75 XR32TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9,3 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS cUTrlNG GAS 113 PV 9.0 SD METHANE(C-I) 159 @ ETHANE(C-2) 3 @ PROPANE(C-3) 1 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL SIN JETS MG1214 3X18 71.2 9225 50 5 3529 INTERVAL IN 13195 HIGH DEPTH: 13268' 23 YP OIL OUT 13246 13257 5.0 13265 -133 13246 1 13260 1 13254 2372 18 75% FOOTAGE 51 LOW @ 13256 @ 13249 @ 13257 @ 13257 @ 13257 FL 6.8 MBL HIGH LOW 13257 0 @ 13256 CHROMATOGRAPHY(ppm) 13257 45 @ 13256 13246 1 @ 13251 13246 1 @ 13250 13270 0 @ 13270 13270 0 @ 13270 NO SHOWS LITHOLOGY/REMARKS AVERAGE 1.3 110.2 0.5 0.2 0.0 0.0 LITHOLOGY SAND (80%), CONGLOMERATIC SAND (10%), TUFFACEOUS CLAY (lO%) SAND (80%), CONGLOMERATIC SAND (10%), TUFFACEOUS CLAY PRESENT LITHOLOGY (10%) DAILY ACTIVITY SUMMARY EPOCH PRESENT OPERATION= DRILLING AZIMUTH VERTICAL DEPTH CONDITION HOURS T/B/C 6.6 (ON BO'TI'OM) AVERAGE CURRENT AVG 15.2 6.3 5266.3 8700.8 16.5 7.3 2,5 5 3436.5 3463 Gels 23/28/34 CL- 36000 pH Ca+ REASON PULLED DTF fi/hr amps Klbs RPM psi CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 1.3 CURRENT 1.74 CURRENT BACKGROUND/AVG 1.49 GAS DESCRIPTION PULLED OUT OF HOLE, LAID DOWN BHA, TEST BOP, PICKED UP BHA (WITHOUT LVVD TOOL), DRILLED 13246 TO 13275 FEET. Epoch Personet On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WNIRU #7 ST #1 REPORT FOR MIKE MELLO DATE Mar 20, 2001 TIME 04:06:17 DAILY WELLSITE REPORT DEPTH 13246 YESTERDAY 13195 24 Hour Footage 51 EPOCH CASING INFORMATION 9.625" @ 6535" 7.625" @ 12950' PRESENT OPERATION= PULLING OUT OF HOLE DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13177.08 83.85 54.90 9532.95 13194.00 87.63 55 9541.89 SURVEY DATA INTERVAL SIN JETS IN OUT MG1214 3X18 13195 13246 ! 55.5 9136 64 4 3623 i BIT INFORMATION NO. SIZE TYPE 21 6.75 XR32TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS HIGH @ 13236 @ 13229 @ 13242 @ 13227 @ 13232 DEPTH: 13246 25 YP OIL 2,6 -238 7 1 2412 19 75% 108 PV 7.66 SD FOOTAGE 51 LOW FL MBL 13203 13237 13219 13245 13195 i GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 2 @ 13195 0 @ 13218 0.9 CUTTING GAS @ @ CHROMATOGRAPHY(ppm) METHANE(C-I) 173 @ 13195 13 @ 13214 56.1 ETHAN E(C-2) 18 @ 13195 1 @ 13218 3.0 PROPANE(C-3) 2 @ 13229 1 @ 13246 0,6 BUTANE(C-4) 0 @ 13246 0 @ 13246 0.0 PENTANE(C-5) 0 @ 13246 0 @ 13246 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS 6.8 HOURS 6.6 (ON BOTTOM) AVERAGE 17,3 2218.7 26.8 1.1 3430.4 Gels pH 26/35/38 CONDITION REASON T/B/C PULLED IN HOLE CURRENT AVG 12.3 fi/hr 674.3 amps 50.0 Klbs 3 RPM 3502 psi CL- 34000 Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 0.9 CURRENT 1.24 CURRENT BACKGROUND/AVG 1.24 iiiii ii GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE CONGLOMERATE, TUFFACEOUS SILTSTONE, TUFF, TUFFACEOUS CLAY PRESENT LITHOLOGY SAND, SANDSTONE CONGLOMERATE, TUFFACEOUS SILTSTONE, TUFF DAILY ACTIVITY SUMMARY DRILLED 13195 TO 13246 FEET, LWD TOOL FAILED TO OPERATE, PULLING OUT OF HOLE. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE Mar 19, 2001 TIME 04:03:22 DAILY WELLSITE REPORT DEPTH 13195 YESTERDAY 13193 24 Hour Footage 2 CASING INFORMATION 9,625" @ 6535' 7.625" @ 12950' (COORECTED CASING DEPTH) DEPTH INCLINATION SURVEY DATA 13140.03 73.24 HIGH LOW AVERAGE 2 @ 13194 2 @ 13193 3.6 CHROMATOGRAPHY(ppm) METHANE(C-I) 369 @ 13194 173 @ 13195 434.0 ETHANE(C.2) 40 @ 13194 18 @ 13195 47.0 PROPANE(C-3) 5 @ 13193 3 @ 13194 4,0 BUTANE(C-4) 0 @ 13195 0 @ 13195 0.0 PENTANE(C-5) 0 @ 13195 0 @ 13195 0,0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGYIREMARKS ii BIT INFORMATION INTERVAL NO. SIZE 'rYPE SIN JETS IN OUT FOOTAGE 20 6.75 XR32TDGPS MG1216 3X18 13073 13195 122 21 6.75 XR32TDGPS MG1214 3X18 13195 DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 15.1 (~ 13193 9.7 SURFACE TORQUE 4165 @ 13195 797 WEIGHT ON BIT 43 @ 13193 13 ROTARY RPM 5 @ 13194 2 PUMP PRESSURE 3530 @ 13194 2412 @ DRILLING MUD REPORT DEPTH: 13195 MW 9.4 VIS 140 PV 24 YP 21 FI. FC /2 SOL 8,54 SD OIL 74% MBL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS EPOCH PRESENT OPERATION= RUNNING IN HOLE AZIMUTH VERTICAL DEPTH 55.58 9529 CONDITION REASON HOURS T/B/C PULLED 13.1 (ON BOTTOM) PENE RATE AVERAGE CURRENT AVG 13195 17,3 9,7 fi/hr 13193 3101.6 4165.7 amps 13195 48.7 13.3 Klbs 13195 4.5 2 RPM 13195 4724.0 2412 psi ! 6,8 Gels 27/35/39 CL- 36500 pH Ca+ GAS CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 2.4 CURRENT 2.48 CURRENT BACKGROUND/AVG 2.48 LITHOLOGY SAND, CONGLOMERATIC SANDSTONE, TUFF, TUFFACEOUS CLAY PRESENT LITHOLOGY SAND, CONGLOMERATIC SANDSTONE, TUFF, TUFFACEOUS CLAY DAILY ACTIVITY SUMMARY DRILLED 13193 TO 13195', PULLED OUT OF HOLE FOR NEW BIT, RUNNING IN HOLE DESCRIPTION Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE Mar 18, 2001 TIME 04:02:58 DALLY WELLSITE REPORT DEPTH 13193 YESTERDAY 13073 EPOCH PRESENT OPERATION= DRILLING (SLIDING) 24 Hour Footage 120 CASING INFORMATION 9.625" @ 6535' 7.625" @ 12946' DEPTH INCLINATION 12950.28 39.39 13011.64 48.02 SURVEY DATA 13041.55 52.53 13066.82 56.87 13109.87 65.32 BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN OUT 20 6,75 XR32TDGPS MG1216 3X18 13073 DRILLING PARAMETERS HIGH RATE OF PENETRATION 283.5 @ 13135 1.5 SURFACE TORQUE 1711 @ 13121 0 WEIGHT ON BIT 53 @ 13109 1 ROTARY RPM 7 @ 13176 1 PUMP PRESSURE 3615 @ 13158 2680 DRILLING MUD REPORT DEPTH: 13195 MW 9.3 VIS 124 PV 25 YP 25 FC /2 SOL 8.54 SD OIL 74% MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH DITCH GAS 4 CUTTING GAS LOW FL MBL LOW 13154 0 @ 13169 CHROMATOGRAPHY(ppm) METHANE(C-I) 10043 (~ 13181 25 @ 13169 652.5 ETHANE(C-2) 10066 @ 13181 2 @ 13103 465.3 PROPANE(C-3) 10089 @ 13181 1 @ 13103 461.3 BUTANE(C-4) 85 @ 13154 2 ~;! 13176 4.9 PENTANE(C-5) 4 @ 13135 1 @ 13139 0.1 ,, HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS AZIMUTH 52.11 52.37 52.69 53.54 54.98 FOOTAGE HOURS AVERAGE 13155 20.8 13114 420.3 13181 28.1 13185 1.0 13101 3469.9 7.2 Gels pH 27133/38 AVERAGE 1.6 GAS VERTICAL DEPTH 9423.44 9467.75 9486.87 9501.46 9522.46 CONDITION T/B/C CURRENT AVG 8.4 276.2 15.4 1 3541 REASON PULLED IN HOLE CL- 36500 Ca+ fi/hr amps KibE RPM psi CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 1.6 CURRENT 2 CURRENT BACKGROUND/AVG 2 DESCRIPTION LITHOLOGY SAND, CONGLOMERATIC SANDSTONE, TUFF, TUFFACEOUS SILTSTONE, TUFFACEOUS CLAY PRESENT LITHOLOGY SAND, CONGLOMERATIC SANDSTONE, TUFF, TUFFACEOUS CLAY 'DAILY ACTIVITY SUMMARY RAN IN HOLE, DRILLED (SLIDE) 13073 TO 13193 FEET. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE Mar 17, 2001 TIME 04:02:19 DAILY WELLSITE REPORT DEPTH 13073 YESTERDAY 13050 24 Hour Footage 23 CASING INFORMATION 9.825" @ 6535' 7.625" @ 12946' DEPTH SURVEY DATA INCLINATION EPOCH PRESENT OPERATION= RUNNING IN HOLE AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE S/N 19 6.75 XR20TDG LY9626 20 6.75 XR32TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE VVEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC /2 SOL 145 PV 8.0 SD ,, MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS 41.7 353 25 0 3604 INTERVAL JETS IN 3X16 12950 3Xl 8 13073 HIGH @ 13054 @ 13066 @ 13060 @ 13068 @ 13050 DEPTH: 13073 26 YP OIL OUT FOOTAGE 13073 123 LOW 4.0 @ 13064 -151 @ 13063 10 @ 13066 0 @ 13068 3539 @ 13O65 24 FL 6,8 74.5% MBL HIGH LOW AVERAGE @ 13051 1 @ 13068 2.5 CHROMATOGRAPHY(ppi) METHANE(C-I) 338 @ 13051 178 @ 13084 257 ETHANE(C-2) 33 @ 13051 17 @ 13064 25 PROPANE(C-3) 29 @ 13051 13 @ 13064 21 BUTAN E(C-4) 11 @ 13065 1 @ 13051 6 PENTANE(C-5) 0 @ 13065 0 @ 13065 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS CONDITION HOURS T/B/C REASON PULLED BHA AVERAGE CURRENT AVG 15,5 11.5 fi/hr 21.6 -11.7 amps 22.2 21.5 Klbs 0,0 0 RPM 3772,2 3550 psi Gels 27/33/38 CL- 36500 pH Ca+ Gas CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= 2.5 CURRENT 2 CURRENT BACKGROUND/AVG 3 DESCRIPTION LITHOLOGY CONGLOMERATIC SANDSTONE AND TUFF PRESENT LITHOLOGY CONGLOMERATIC SANDSTONE (80%) AND TUFF (20%) DAILY ACTIVITY SUMMARY DRILLED 13050 TO 13073 FEET. PULLED OUT OF HOLE FOR NEW BHA. MADE Up NEW BHA, RUNNING IN HOLE, HOLE. Epoch Personel On Board= 4 Daily Cost $2850 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DATE Mar 16, 2001 TIME 04:03:27 DAILY WELLSITE REPORT DEPTH 13050 YESTERDAY 12950 24 Hour Footage 100 CASING INFORMATION 9.625" @ 6535' 7.625" @ 12946' DEPTH SURVEY DATA INCLI NATION EPOCH PRESENT OPERATION= DRILLING AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 20 6.75 XR20TDG DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS 126 PV 8.5 SD SIN LY9626 INTERVAL JETS IN 3X16 12950 116.8 16589 28 5O 3644 OUT HIGH @ 12954 4.7 @ 12950 -111 @ 12974 0 @ 12950 1 @ 13003 2719 DEPTH: 13037 26 YP 23 OIL 74% GAS SUMMARY(units) HIGH LOW DITCH GAS 36 @ 13008 15 @ 12988 CU'I-rlNG GAS @ @ CHROMATOGRAPHY(ppm) METHANE(C-I) 6486 @ 13008 2718 @ 12988 ETHAN E(C-2) 310 @ 12950 113 @ 13004 PROPANE(C-3) 126 @ 13008 51 @ 12988 BUTANE(C-4) 15 @ 12950 1 @ 13018 PENTANE(C-5) 0 @ 0 0 @ 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY CONGLOMERATIC SANDSTONE, TUFF, TUFFACEOUS CLAY PRESENT LITHOLOGY CONGLOMERATIC SANDSTONE, TUFF DAILY ACTIVITY SUMMARY FOOTAGE LOW @ 12998 @ 13029 @ 12960 @ 13034 @ 12950 FL 7.0 MBL CONDITION REASON HOURS T/B/C PULLED AVERAGE 16.6 362.8 14.8 1.2 3580.7 Gels 29/34/37 pH CURRENT AVG 14.8 fi/hr 497.0 amps 24.6 Klbs 1 RPM 3547 psi CL- Ca+ 36500 CCI AVERAGE 27.6 TRIP GAS= WIPER GAS= SURVEY= 4886.4 CONNECTION GAS HIGH= 199.2 AVG= 27.6 92.9 CURRENT 34 5.2 CURRENT BACKGROUND/AVG 32 0.0 GAS DESCRIPTION DRILLED OUT LANDING COLLAR AT 7 5/8" CASING SHOE, DRILLED 12950 TO 12970 FEET, PERFORMED FIT TEST TO 10.5 PPG EQUIVALENT, DRILLED 12970 TO 13050 FEET. Epoch Personel On Board= 4 Daily Cost $2245 Report by: LOWELL PRICE FOREST OIL CORP WI~RU #7 ST #1 REPORT FOR MIKE MELLO DATE Mar 15, 2001 TIME O4:01:18 DALLY VVELLSITE REPORT DEPTH 12950 YESTERDAY 12950 24 Hour Footage 0 CASING INFORMATION 9.625" @ 6535' 7.625" @ 12946' DEPTH SURVEY DATA BIT INFORMATION NO. SIZE TYPE SIN JETS 20 6.75 XR20TDG LY9626 3X16 INCLINA~ON INTERVAL IN OUT 12950 EPOCH PRESENT OPERATION= RUNNING IN HOLE AZIMUTH FOOTAGE HOURS 0 0 VERTICAL DEPTH CONDITION REASON T/B/C PULLED DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 11.3 @ 12950 11.3 SURFACE TORQUE 16589 @ 12950 16589 WEIGHT ON BIT 27 @ 12950 27 ROTARY RPM 50 @ 12950 50 @ PUMP PRESSURE 2719 @ 12950 2719 @ DRILLING MUD REPORT DEPTH: 12950 MW 9.5 VIS 140 PV 24 YP 24 FL FC /2 SOL 8.54 SD OIL 74% MBL MVVD SUMMARY 12950 12950 12950 12950 12950 7.0 AVERAGE Gels 27131/37 pH INTERVAL TOOLS TO GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 13 @ 12950 13 @ 12950 13 CUTTING GAS @ CHROMATOGRAPHY(ppm) METHANE(C-I) 2407 @ 12950 2407 @ 12950 2407 ETHANE(C-2) 79 @ 12950 79 @ 12950 79 PROPANE(C-3) 34 @ 12950 34 @ 12950 34 BUTANE(C-4) 3 @ 12950 3 @ 12950 3 PENTANE(C-5) 0 @ 12950 0 @ 12950 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY CURRENT AVG 11.3 fi/hr 16589.6 amps 27.5 Klbs 5O RPM 2719 psi CL- 36500 Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION TUFF (70%), CONGLOMERATIC SANDSTONE (10%), AND COAL (20% - PROBABLE SLUFF - LARGER PRESENT LITHOLOGY FRAGMENTS) DAILY ACTIVITY SUMMARY RIH WITH 3.5" DRILL PIPE, PERFORMED CASING PRESSURE TEST - PASSED, POH, PICKED UP MUD MOTOR, RIH TO DRILL OUT CEMENT AT 7.625" CASING SHOE. Epoch Personel On Board= 4 Daily Cost $2245 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DATE Mar 14, 2001 TIME 04:03:17 DALLY WELLSITE REPORT DEPTH 12950 YESTERDAY 12950 24 Hour Footage 0 CASING INFORMATION 9.625" @ 6535' 7.625" @ 12946' DEPTH SURVEY DATA EPOCH PRESENT OPERATION= PICKING UP 3 1/2" DRILL PIPE INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL NO. SIZE TYPE SIN JETS IN 18 8.5 STC 20MFDGDP LW1717 3X18 12387 DRILLING PARAMETERS HIGH RATE OF PENETRATION 11.3 @ 12950 SURFACE TORQUE 16589 @ 12950 WEIGHT ON BIT 27 @ 12950 ROTARY RPM 50 @ 12950 PUMP PRESSURE 2719 @ 12950 DRILLING MUD REPORT DEPTH: 12950 29 YP OIL OUT 12950 ! 130 PV 8.52 SD 11.3 16589 27 5O 2719 CONDITION FOOTAGE HOURS T/B/C 563 19.6 (ON BOTTOM) LOW AVERAGE CURRENT AVG @ 12950 11.3 @ 12950 16589.6 @ 12950 27.5 @ 12950 50 @ 12950 2719 MW 9.4 ViS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 13 @ 12950 13 @ 12950 13 CUTTING GAS CHROMATOGRAPHY(ppm) METHANE(C-I) 2407 @ 12950 2407 @ 12950 2407 ETHANE(C-2) 79 @ 12950 79 @ 12950 79 PROPANE(C-3) 34 @ 12950 34 @ 12950 34 BUTANE(C-4) 3 @ 12950 3 @ 12950 3 PENTANE(C-5) 0 @ 12950 0 @ 12950 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY 19 FL 7.0 Gels 28134/39 CL- 37000 74% MBL pH Ca+ REASON PULLED LOG/CASE fi/hr amps Klbs RPM psi CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION TUFF (70%), CONGLOMERATIC SANDSTONE (10%), AND COAL (20% - PROBABLE SLUFF - LARGER PRESENT LITHOLOGY FRAGMENTS) DAILY ACTIVITY SUMMARY PULLED OUT OF HOLE. CHANGED RAMS ON BOP. TESTED BOP. PICKING UP 3 1/2" DRILL PIPE. Epoch Personel On Board= 1 Daily Cost $2053 Report by: LOWELL PRICE FOREST OIL CORP DAILY WELLSITE REPORT WMRU #7 ST #1 REPORT FOR DATE Mar 14, 2001 DEPTH 12950 TIME 04:03:17 YESTERDAY 12950 24 Hour Footage 0 ! CASING INFORMATION 9.625"@ 6535' 7.625" @ 12946' DEPTH SURVEY DATA BIT INFORMATION NO. SIZE TYPE S/N JETS 18 8.5 STC 20MFDGDP LW1717 3X18 EPOCH INCLINATION INTERVAL IN OUT FOOTAGE 12387 12950 563 PRESENT OPERATION= PICKING UP 3 1/2" DRILL PIPE AZIMUTH HOURS 19.8 (ON BOTTOM) VERTICAL DEPTH CONDITION REASON T/B/C PULLED LOG/CASE DRILLING PARAMETERS HIGH LOW RATE OF PENETRATION 11.3 @ 12950 11.3 SURFACE TORQUE 16589 @ 12950 16589 WEIGHT ON BIT 27 @ 12950 27 ROTARY RPM 50 @ 12950 50 PUMP PRESSURE 2719 @ 12950 2719 DRILLING MUD REPORT DEPTH: 12950 MW 9,4 VIS 130 PV 29 YP 19 FL FC /2 SOL 8.52 SD OIL 74% MBL MWD SUMMARY INTERVAL TO TOOLS 12950 12950 12950 12950 12950 7,0 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 13 @ 12950 13 @ 12950 13 CUTTING GAS CH ROMATOG RAPHY(ppm) METHANE(C-I) 2407 @ 12950 2407 @ 12950 2407 ETHAN E(C-2) 79 @ 12950 79 (~ 12950 79 PROPANE(C-3) 34 (~ 12950 34 @ 12950 34 BUTANE(C-4) 3 @ 12950 3 @ 12950 3 PENTANE(C-5) 0 @ 12950 0 @ 12950 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY AVERAGE Gels pH 28/34/39 CURRENT AVG 11.3 fi/hr 16589.6 amps 27.5 Klbs 5O RPM 2719 psi CL- 37000 Ca+ CCI TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION i i ii TUFF (70%), CONGLOMERATIC SANDSTONE (10%), AND COAL (20% - PROBABLE SLUFF - LARGER PRESENT LITHOLOGY FRAGMENTS) DAILY ACTIVITY SUMMARY PULLED OUT OF HOLE. CHANGED RAMS ON BOP. TESTED BOP. PICKING UP 3 1/2" DRILL PIPE, Epoch Personel On Board= 1 Daily Cost $2053 Report by: 'LOWELL PRICE FOREST OIL CORP DALLY WELLSITE REPORT WMRU fr7 ST #1 REPORT FOR DATE Mar 13, 2001 DEPTH 12950 TIME 04:06:32 YESTERDAY 12950 EPOCH PRESENT OPERATION= PULLING OUT OF HOLE 24 Hour Footage 0 CASING INFORMATION 9.625" 2 6535' 7.625" @ 12946' DEPTH SURVEY DATA INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE S/N 18 8.5 STC 20MFDGDP LW1717 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS 130 PV FC /2 SOL 8.52 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS 13 CUTTING GAS INTERVAL 11.3 16589 27 50 2719 JETS IN OUT FOOTAGE 3X18 12387 12950 563 HIGH LOW @ 12950 11.3 @ 12950 @ 12950 16589 @ 12950 @ 12950 27 @ 12950 @ 12950 50 @ 12950 @ 12950 2719 @ 12950 DEPTH: 12950 26 YP 22 FL 7.0 OIL 74% MBL HIGH LOW AVERAGE @ 12950 13 @ 12950 13 @ @ CHROMATOGRAPHY(ppm) CONDITION REASON HOURS T/B/C PULLED 19.6 (ON BO'I-I'OM) LOG/CASE AVERAGE CURRENT AVG 11.3 11.3 fi/hr 16589.6 16589.6 amps 27.5 27.5 Klbs 50 5O RPM 2719 2719 psi . Gels 27/32138 CL- 3700 pH Ca+ CCI METHANE(C-I) 2407 @ 12950 2407 @ 12950 2407 ETHANE(C-2) 79 @ 12950 79 @ 12950 79 PROPANE(C-3) 34 @ 12950 34 @ 12950 34 BUTAN E(C-4) 3 @ 12950 3 @ 12950 3 PENTANE(C-5) 0 @ 12950 0 @ 12950 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG GAS DESCRIPTION TUFF (70%), CONGLOMERATIC SANDSTONE (10%), AND COAL (20% - PROBABLE SLUFF - LARGER PRESENT LITHOLOGY FRAGMENTS) DAILY ACTIVITY SUMMARY CEMENTED 7.625" CASING, TOP @ 6321', BASE @ 12946'. Epoch Personel On Board= 1 Daily Cost $2053 Report by: LOWELL PRICE FOREST OIL CORP V~vlRU #7 ST #1 REPORT FOR DATE Mar 12, 2001 TIME 04:03:05 CASING INFORMATION 9.625" @ 6535' SURVEY DATA DALLY WELLSITE REPORT DEPTH 12950 YESTERDAY 12950 24 Hour Footage 0 DEPTH INCLINATION EPOCH PRESENT OPERATION= RUNNING 7 5/8" CASING AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE S/N 18 8.5 STC 20MFDGDP LW1717 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS 118 PV FC /2 SOL 8.52 SD MWD SUMMARY INTERVAL TO TOOLS INTERVAL 11.3 16589 27 5O 2719 JETS IN 3X18 12387 HIGH @ 12950 @ 1295O @ 12950 @ 12950 @ 12950 DEPTH: 12950 28 YP OIL OUT 12950 FOOTAGE 563 LOW 11.3 @ 12950 16589 @ 12950 27 @ 12950 50 @ 12950 2719 @ 1295O 22 FL 7.0 74% MBL HOURS 19.6(ONBOTTOM) AVERAGE Gels 28/33/38 pH CONDITION T/B/C CURRENT AVG 11.3 16589.6 27.5 5O 2719 CL. 37000 Ca+ REASON PULLED LOG/CASE ft/hr amps Klbs RPM psi CCI GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 13 @ 12950 13 @ 12950 13 CUTTING GAS CHROMATOGRAPHY(ppm) METHANE(C-I) 2407 @ 12950 2407 @ 12950 2407 ETHANE(C-2) 79 @ 12950 79 @ 12950 79 PROPANE(C-3) 34 @ 12950 34 @ 12950 34 BUTANE(C-4) 3 @ 12950 3 @ 12950 3 PENTANE(C-5) 0 @ 12950 0 @ 12950 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY GAS TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG DESCRIPTION TUFF (70%), CONGLOMERATIC SANDSTONE (10%), AND COAL (20% - PROBABLE SLUFF - LARGER PRESENT LITHOLOGY FRAGMENTS) DAILY ACTIVITY SUMMARY RUNNING 7 5/8" CASING. Epoch Personel On Board= 1 Daily Cost $2053 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DATE Mar 11, 2001 TIME 04:06:19 CASING INFORMATION 9.625" @ 6535' SURVEY DATA DAILY VVELLSITE REPORT DEPTH 12950 YESTERDAY 12950 24 Hour Footage 0 DEPTH EPOCH PRESENT OPERATION= RUNNING CASING INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE SIN JETS 18 8.5 STC 20MFDGDP LW1717 3X18 INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 12387 12950 563 19.6 (ON BOTTOM) LOG/CASE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC 12 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 HIGH LOW AVERAGE CURRENTAVG 11.3 @ 12950 11.3 @ 12950 11.3 ~hr 16589 @ 12950 16589 @ 12950 16589.6 amps 27 @ 12950 27 @ 1295O 27.5 Klbs 50 @ 12950 50 @ 12950 50 RPM 2719 @ 12950 2719 @ 1295O 2719 psi DEPTH: 12950 120 PV 29 YP 19 FL 7,0 Gels 27/34/40 CL- 37000 8.54 SD OIL 75% MBL pH Ca+ CCI HIGH LOW AVERAGE 13 @ 12950 13 @ 12950 13 TRIP GAS= @ @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 2407 @ 12950 2407 @ 12950 2407 CONNECTION GAS HIGH= 79 @ 12950 79 @ 12950 79 AVG= 34 @ 12950 34 @ 12950 34 CURRENT 3 @ 12950 3 @ 12950 3 CURRENT BACKGROUND/AVG 0 @ 12950 0 @ 12950 0 NO SHOWS LITHOLOGY/REMARKS GAS DESCRIPTION PRESENT LITHOLOGY TUFF, SANDSTONE CONGLOMERATE, AND COAL (PROI~ABLE SLUFF - LARGER FRAGMENTS) DAILY ACTIVITY PULLED OUT OF HOLE. LAID DOWN HEAVY WALL DRILL PIPE AND BHA. rig UP WEATHERFORD TO RUN CASING. SUMMARY RUNNING CASING. Epoch Personel On Board= I Daily Cost $2053 Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DATE Mar 10, 2001 TIME 04:00:56 CASING INFORMATION 9.625" @ 6535' SURVEY DATA BIT INFORMATION NO. SIZE 18 8.5 TYPE STC 20MFDGDP DALLY WELLSITE REPORT DEPTH 12950 YESTERDAY 12950 24 Hour Footage 0 DEPTH S/N LW1717 INCLINATION INTERVAL JETS IN OUT 3X18 12387 12950 FOOTAGE 563 EPOCH PRESENT OPERATION= PULLING OUT OF HOLE AZIMUTH VERTICAL DEPTH HOURS 19.6 (ON BOq-I'OM) CONDITION T/B/C ..= REASON PULLED LOG/CASE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC /2 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 103 8.54 PV SD 11.3 16589 27 50 2719 HIGH @ 12950 11.3 @ 12950 16589 @ 12950 27 @ 12950 50 @ 12950 2719 DEPTH: 12950 26 YP 20 OIL 73% LOW FL MBL 0 12950 12950 12950 12950 ,, 6.8 AVERAGE Gels pH CURRENT AVG 11.3 16589.6 27.5 5O 2719 25/28/31 CL- Ca+ 37000 fi/hr amps Klbs RPM psi CCI 13 0 2407 79 34 3 0 HIGH LOW 12950 13 @ 12950 12950 0 @ 12950 CHROMATOGRAPHY(ppm) 12950 2407 @ 12950 12950 79 @ 12950 12950 34 @ 12950 12950 3 @ 12950 12950 0 @ 12950 AVERAGE NO SHOWS LITHOLOGY/REMARKS GAS TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG DESCRIPTION PRESENT LITHOLOGY TUFF, SANDSTONE CONGLOMERATE, AND COAL (PROBABLE SLUFF - LARGER FRAGMENTS) DAILY ACTIVITY RAN TO BOTTOM OF HOLE. PUMPED HI VIS SVVEEP. CIRCULATED HOLE CLEAN. SHORT TRIP TO SHOE. RAN IN HOLE FOR SUMMARY WIPER TRIP, PULLING OUT OF HOLE, Epoch Personel On Board= I Daily Cost Report by: LOWELL PRICE FOREST OIL CORP WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE Mar 09, 2001 TIME 04:00:00 CASING INFORMATION 9.625' (~ 6535' SURVEY DATA DEPTH DALLY WELLSITE REPORT DEPTH 12950 YESTERDAY 12950 24 Hour Footage 0 I NCLI NATION EPOCH PRESENT OPERATION= WIPING HOLE AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE TYPE 18 8.5 STC 20MFDGDP DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE ,., DRILLING MUD REPORT MW 9.4 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I-FING GAS 107 8.0 S/N LW1717 INTERVAL JETS IN OUT 3X18 12387 12950 PV SD HIGH 11.3 @ 12950 11.3 16589 @ 12950 16589 27 @ 12950 27 5O @ 1295O 5O 2719 @ 12950 2719 DEPTH: 12950'(MD) 26 YP 19 OIL 74 13 0 CONDITION FOOTAGE HOURS T/BIC 563 19.6 (ON BO'I-rOM) ,, LOW AVERAGE CURRENT AVG @ 12950 11.3 11.3 @ 12950 16589 16589.6 @ 12950 27 27,5 @ 1295O 5O 5O @ 12950 2719 2719 FL 6,8 Gels 24/30/34 CL- MBL pH Ca+ REASON PULLED LOG/CASE E/hr amps Klbs RPM psi 37000 CCI HIGH LOW AVERAGE @ 12950 13 @ 12950 13 @ 0 0 @ 0 0 CHROMATOGRAPHY(ppm) METHANE(C-I) 2407 @ 12950 2407 @ 12950 2407 ETHANE(C-2) 79 @ 12950 79 @ 12950 79 PROPANE(C-3) 34 @ 12950 34 @ 12950 34 BUTANE(C-4) 3 @ 12950 3 @ 12950 3 PENTANE(C-5) 0 @ 12950 0 @ 12950 0 HYDROCARBON SHOWS NO SHOWS. INTERVAL LITHOLOGY/REMARKS LITHOLOGY GAS TRIP GAS= WIPER GAS= SURVEY= CONNECTION GAS HIGH= AVG= CURRENT CURRENT BACKGROUND/AVG DESCRIPTION PRESENT LITHOLOGY TUFF, SANDSTONE CONGLOMERATE, AND COAL (PROBABLE SLUFF - LARGER FRAGMENTS). DAILY ACTIVITY PUMPED HI VIS SWEEP. PULLED OUT OF HOLE. RIGGED UP SCHLUMBERGER. RAN QUAD COMBO ELECTRIC LOGS, SUMMARY RUNNING IN HOLE TO CLEAN HOLE. Epoch Personel On Board= 1 Daily Cost Report by: LOWELL PRICE FOREST OIL CORP V~4RU #7 ST #1 REPORT FOR DATE Mar 08, 2001 TIME 04:00 CASING INFORMATION 9.625" @ 6535' SURVEY DATA DAILY WELLSITE REPORT DEPTH 1295O YESTERDAY 12480 24 Hour Footage 470 , DEPTH 12533,93 12627.41 12720.99 12811.61 12872.62 BIT INFORMATION NO. SIZE TYPE S/N 18 8.5 STC 20MFDGDP LW1717 DRILLING PARAMETERS RATE OF PENETRATION 304.4 SURFACE TORQUE 19086 WEIGHT ON BIT 87 ROTARY RPM 54 PUMP PRESSURE 3219 DRILLING MUD REPORT MW 9.3 VIS 90 PV FC /2 SOL 8.04 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH DITCH GAS 63 CU'I-rlNG GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) ,, INCLINATION 43.44 41.39 39.93 39.40 39.28 INTERVAL JETS IN OUT FOOTAGE 3X18 12387 HIGH LOW @ 12686 5.8 @ 12690 @ 12784 -407 @ 12688 @ 12568 1 @ 12702 @ 12613 I @ 12772 @ 12655 1576 @ 12522 , ~, DEPTH: 12950 28 YP 19 FL 6,8 OIL 74% MBL EPOCH PRESENT OPERATION= PUMPING SWEEP AZIMUTH VERTICAL DEPTH 79.65 9106.23 70.39 9175.31 59.97 9246.38 51.36 9316.19 52.11 9363.37 CONDITION HOURS T/B/C 19.6 (ON BO'FI'OM) AVERAGE CURRENT AVG 47,4 11.3 ft/hr 8370.2 16589.6 amps 40.1 27.5 Klbs 24.1 50 R PM 3014,9 2719 psi REASON PULLED IN HOLE Gels 25/29/34 CL- 36500 pH Ca+ CCI LOW AVERAGE 12524 13 @ 12950 29.2 TRIP GAS= @ WIPER GAS= CHROMATOGRAPHY(ppm) SURVEY= 14320 @ 12523 2407 @ 12950 5650.5 CONNECTION GAS HIGH= 12 266 @ 12945 18 @ 12805 53.9 AVG= 29.2 150 @ 12945 1 @ 12916 10.6 CURRENT 13 26 @ 12945 I @ 12936 0.6 CURRENT BACKGROUND/AVG 34 0 @ 12950 0 @ 12950 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFF, COAL, CONGLOMERATIC SANDSTONE TUFF (70%), CONGLOMERATIC SANDSTONE (10%), AND COAL (20% - PROBABLE SLUFF - LARGER PRESENT LITHOLOGY FRAGMENTS) , DAILY ACTIVITY SUMMARY DRILLED 12480' TO 12950'. CIRCULATED. PUMPING HI VIS SWEEP. Epoch Personel On Board= 4 Daily Cost $2245 Report by: LOWELL PRICE FOREST OIL CORP [-I EPOCH WMRU #7 ST #1 REPORT FOR DATE Mar 05, 2001 DEPTH 12046 PRESENT OPERATION= SHORT TRIP TIME 04:00 YESTERDAY 11614 24 Hour Footage 432 CASING INFORMATION 9.625" @ 6535' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11968.66 43.74 126.68 8693.16 · iiii i i i BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 17 8.5" SEC XS12 741513 2X16, 1X18 11484 23 ,,, DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 177.8 @ 11765 6.6 @ 11614 34.8 21.2 E/hr SURFACE TORQUE 19225 @ 11765 11228 @ 11614 16888.6 17188.5 amps WEIGHT ON BIT 33 @ 11982 6 @ 11804 25.1 15.9 Klbs ROTARY RPM 79 @ 11770 18 @ 11959 60,3 59 RPM PUMP PRESSURE 3144 @ 11927 1801 @ 11899 2888.0 1959 psi DRILLING MUD REPORT DEPTH: 11567 MW 9.2 VIS 106 PV 25 YP 20 FL Gels 27/32/35 CL- 36000 FC /2 SOL 7.6 SD OIL 73% MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 115 @ 11678 22 @ 12005 38.8 TRIP GAS= 0 CUTTING GAS 0 @ 0 0 @ 0 0.0 WIPER GAS= NA CHROMATOGRAPHY(ppm) SURVEY= 0 METHANE(C-I) 25378 @ 11677 4857 @ 11917 7726.4 CONNECTION GAS HIGH= 18 ETHANE(C-2) 92 @ 11677 5 @ 11971 36.6 AVG= 15 PROPANE(C-3) 28 @ 11677 1 @ 12022 0.3 CURRENT 18 BUTANE(C-4) 0 @ 0 0 @ 0 0,0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 11800 - 11990'= 40% SAND, 20% SILT, 30% CLAY, 10% COAL PRESENT LITHOLOGY 12040' = 60% CLAY, 30% SILT, 10% ASH DAILY ACTIVITY SUMMARY DRILL TO 11786', CIRCULATE SWEEP, DRILL TO 12046', SHORT TRiP PIPE. Epoch Personel On Board= 4 Daily Cost $2245 Report by: LEES F. BROWNE JR. FOREST OIL CORP WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 04, 2001 TIME 03:04:54 CASING INFORMATION 9.625" @ 6535' SURVEY DATA DAILY WELLSITE REPORT EPOCH DEPTH 11613 YESTERDAY 11485 24 Hour Footage 128 PRESENT OPERATION= DRILLING FORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL NO. SIZE TYPE S/N JETS IN 16 8.5" HYCA DS75 HF 1982 2X14, 2X15 10096 17 8.5" SEC XS12 741513 2X16, lX18 11484 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS 96 7.66 GAS SUMMARY(units) HIGH DITCH GAS 100 @ CUTTING GAS 0 METHANE(C-I) 20024 @ ETHANE(C-2) 97 @ PROPANE(C-3) 18 @ BUTANE(C-4) 0 @ PENTANE(C-5) 0 @ HYDROCARBON SHOWS INTERVAL HIGH 159.6 @ 11541 4.1 17172 @ 11556 SLIDE 69 @ 11611 6 63 @ 11548 SLIDE 2972 @ 11600 2456 DEPTH: 11489 PV 26 YP 21 SD OIL 75% OUT 11484 CONDITION REASON FOOTAGE HOURS T/B/C PULLED 1388 56 2/1-X-1/16 PR 5.8 LOW AVERAGE CURRENT AVG @ 11510 40.3 29.4 ftJhr @ 11584 4504.9 SLIDE amps @ 11487 47.0 64.5 Klbs @ 11585 16.7 SLIDE RPM @ 11498 2838.0 2950 psi FL MBL LOW AVERAGE 11545 32 @ 11500 46.5 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) 11545 6178 @ 11500 9038.2 11611 30 @ 11547 277.3 11611 0 @ 11613 0.3 o o @ o o.o 0 0 @ 0 0.o NO SHOWS LITHOLOGY/REMARKS LITHOLOGY 11490 - 11550' = COAL 10%, SAND 40%, ASH 10%, SILT 40%, PRESENT LITHOLOGY 11610'= CLAY 70% SAND 20% SILT 10% DAILY ACTIVITY SUMMARY Gels 28/31/33 CL- 34000 pH Ca+ CCI TRIP GAS= 160/11484' WIPER GAS= 0 SURVEYTM 0 CONNECTION GAS HIGH= 6 AVG= 6 CURRENT 6 CURRENT BACKGROUND/AVG 48 GAS DESCRIPTION ,! PULL OUT TO 6570', MONITOR WELL, PULL OUT OF THE HOLE, RIG UP AND TEST BOP'S, BHA - LAY DOWN BIT, MOTOR AND JARS, PICK UP NEW MOTOR, JARS AND BIT, RUN IN HWDP, CHANGE FLOAT AND STAB ON MOTOR, RUN IN THE HOLE, CUTAND SLIP DRILL LINE, RUN IN THE HOLE, REAM THE LAST TWO STANDS, CIRCULATE BOTTOMS UP TO WARM OIL BASE MUD, DRILL AHEAD TO REPORT TIME. Epoch Personel On Board= 4 Daily Cost $2245 Report by: LEES F. BROWNE JR. FOREST OIL CORP. WMRU ~ ST #1 REPORT FOR DERRY THOMPSON DATE Mar 02, 2001 TIME 04:00 CASING INFORMATION 9.825"@ 6535' SURVEY DATA i BIT INFORMATION NO. SIZE TYPE 16 8.5 HYCA DS75 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 VIS FC 12 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'CI'ING GAS 103 7.73 DALLY WELLSITE REPORT DEPTH 11250 YESTERDAY 10887 24 Hour Footage 363 DEPTH 11128.86 S/N HF 1982 EPOCH HIGH 164 0 @ METHANE(c-I) 34120 ETHANE(C-2) 142 PROPANE(C-3) 42 BUTANE(C-4) 0 PENTANE(C-5) 0 ,, , , HYDROCARBON SHOWS INTERVAL 306.8 19588 72 70 2741 PV SD INCLINATION 50.47 INTERVAL JETS IN 2X14, 2X15 10096 HIGH @ 11116 2.2 @ 11O13 SLIDE @ 1O9O9 1 @ 11O33 SLIDE @ 11189 2196 DEPTH: 10876' 27 YP 24 OIL 73% ii OUT LOW PRESENT OPERATION= DRILLING FORMATION · AZIMUTH VERTICAL DEPTH 117.42 8122.38 FOOTAGE 112O7 11134 11094 11119 11113 LOW AVERAGE 11057 20 @ 10993 61.1 o o @ o o.o CHROMATOGRAPHY(ppm) 11055 3969 @ 10966 12739.8 11154 9 @ 10966 61.0 11159 1 @ 11051 2.6 0 0 @ 0 0.0 0 0 @ 0 0.0 NO SHOWS LITHOLOGY/REMARKS FL Gels MBL pH CONDITION HOURS T/B/C 43.8 AVERAGE CURRENT AVG 41.4 27.5 14069.3 17997.0 16.5 7.3 47.8 64 2431.2 2480 29/33/34 CL- 33000 Ca+ i ill i i i i REAsoN PULLED LITHOLOGY I0900' - 11200' = 20% COAL, 50% SAND, 30% SILT, 20% CLAY PRESENT LITHOLOGY 11250'= SAND 40% SANDSTONE 10%, ASH 10%, SILT 30%, 10% CLAY DAILY ACTIVITY SUMMARY fi/hr amps Klbs RPM psi CCI TRIP GAS= 0 WIPER GAS= 30/11200' SURVEY= 0 CONNECTION GAS HIGH= 20 AVG= 17 CURRENT 2O CURRENT BACKGROUND/AVG 53 GAS DESCRIPTION DRILL TO 11015', PUMP HI VIS SWEEP, DRILL TO 11199, CIRCULATE OUT SWEEP AND PULL 6 STAND SHORT TRIP, WIPER GAS = 30 UNITS, DRILL AHEAD TO REPORT TIME. Epoch Personel On Board= 4 Daily Cost $2245 Report by: LEES F. BROWNE JR. FOREST OIL CORP. WMRU #7 ST #1 REPORT FOR DERRY THOMPSON DATE Mar 01, 2001 TIME 04:00 DAILY WELLSITE REPORT EPOCH DEPTH 10886 YESTERDAY 10581 24 Hour Footage 305 PRESENT OPERATION= DRILLING FORMATION CASING INFORMATION 9.625" @ 8535' SURVEY DATA BIT INFORMATION NO. SIZE TYPE 16 8.5 HYCA DS75 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.2+ VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'H'ING GAS 109 7.69 DEPTH 10759.10 SIN HF 1982 219.3 19809 62 70 2611 PV SD HIGH o @ INCLINATION 47.97 AZIMUTH VERTICAL DEPTH 107.66 7884.65 CONDITION OUT FOOTAGE HOURS T/B/C 28.42 LOW AVERAGE CURRENT AVG @ 10582 34.9 27.0 @ 10844 7507.7 27.6 @ 10732 26.9 44.5 @ 10819 23.7 SLIDE @ 10732 2480.3 2359 METHANE(C-I) 46624 ETHANE(C-2) 10066 PROPANE(C-3) 10089 BUTANE(C-4) 0 PENTANE(C-5) 0 HYDROCARBON SHOWS INTERVAL INTERVAL JETS IN 2X14, 2X15 10096 HIGH @ 1O717 5.5 @ 1O713 SLIDE @ 10775 0 @ 1O718 SLIDE @ 1O621 2173 DEPTH: 10512' 27 YP 22 OIL 73% LOW AVERAGE 10820 35 @ 10773 71.8 0 0 @ 0 0.0 CH ROMATOGRAPHY(ppm) 10812 6731 @ 10770 15062.7 10886 34 @ 1O7OO 98.0 10886 2 @ 10588 33.9 o o @ o o.o o o @ o o.o NO SHOWS LITHOLOGY/REMARKS FL Gels 28/32/34 CL- MBL pH Ca+ 34000 REASON PULLED fi/hr amps Klbs RPM psi CCI TRIP GAS= 0 WIPER GAS= 44/10732' SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 53 GAS DESCRIPTION LITHOLOGY 10500' - 10800' 30% COAL, 40% SAND, 20% SILT, 10% CLAY PRESENT LITHOLOGY 10800'- 10880' 20% COAL, 10% SAND, 40% SILT, 20% CLAY, 10% ASH DAILY ACTIVITY SUMMARY DRILL TO 10732', PULL 10 STAND SHORT TRIP, DRILL AHEAD TO REPORT DEPTH. Epoch Personel On Board= 4 Daily Cost $2245 Report by: LEES F. BROWNE JR. FOREST OIL CORP WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE Feb 27, 2001 TIME 04:00 DALLY VVELLSITE REPORT DEPTH 1OO94 YESTERDAY 10002 24 Hour Footage 92 DEPTH INCLINATION 1009.29 42.58 HIGH INTERVAL JETS IN OUT 3X16 9662 10096 2X14, 2X15 10096 HIGH LOW @ 10002 3.0 @ 10086 @ 10002 SLIDE @ 10083 @ 10064 15 @ 10002 @ 10089 SLIDE @ 10003 @ 10033 2186 @ 10082 DEPTH: 9957 29 YP 25 FL OIL 72.5 MBL LOW AVERAGE 10002 16 @ 10093 24.9 0 0 @ 0 0.0 CHROMATOGRAPHY(ppm) CASING INFORMATION 9.625" @ 6535' SURVEY DATA BIT INFORMATION NO. SIZE TYPE S/N 15 8.5 STC MFDSSHR LT4853 16 8.5 HYCALOG DS75 HF1982 DRILLING PARAMETERS RATE OF PENETRATION 95.6 SURFACE TORQUE 13462 WEIGHT ON BIT 82 ROTARY RPM 52 PUMP PRESSURE 2609 DRILLING MUD REPORT MW 9.2 VIS 134 PV FC /2 SOL 6.62 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS 34 CUTTING GAS 0 EPOCH PRESENT OPERATION= TRIP IN TO DRILL METHANE(C-I) 6540 @ 10002 ETHANE(C-2) 36 @ 10031 PROPANE(C-3) 5 @ 10094 BUTANE(C-4) 0 @ 0 PENTANE(C-5) 0 @ 0 HYDROCARBON SHOWS INTERVAL , , LITHOLOGY PRESENT LITHOLOGY 10096' 80% SILT, 10% ASH, 10% CLAY DAILY ACTIVITY SUMMARY AZIMUTH VERTICAL DEPTH 53.98 7351.38 CONDITION FOOTAGE HOURS T/B/C 434' 17 8/8-E-1/4 Gels pH AVERAGE CURRENT AVG 21.0 3,9 3802.2 12408.5 50.7 34.6 14.2 50 2447.0 2509 33/38/41 CL- 36000 Ca+ REASON PULLED PR fi/hr amps Klbs RPM psi CCI TRIP GAS= NA WIPER GAS-- 0 SURVEY= 0 478 @ 10087 4153.3 CONNECTION GAS HIGH= 8 2 @ 10090 21.2 AVG= 8 3 @ 10093 0.1 CURRENT 8 0 @ 0 0.0 CURRENT BACKGROUND/AVG 20 o @ o o.o NO SHOWS LITHOLOGY/REMARKS GAS DESCRIPTION DRILL TO 10096', CIRCULATE CUTTINGS OUT, MONITOR WELL, TRIP TO SHOE, MONITOR WELL, TRIP OUT OF THE HOLE, LAY DOWN HWDP, BHA AND BIT, TRIP IN WITH NEW BIT. Epoch Personel On Board= 4 Daily Cost $2245 Report by: LEES F. BROWNE JR FOREST OIL CORP WMRU #7 ST #1 REPORT FOR MIKE MELLO DATE 2/25/2001, TIME 04:00 CASING INFORMATION 9.625" @ 6535' SURVEY DATA DAILY WELLSITE REPORT EPOCH DEPTH 9662 YESTERDAY 9662 24 Hour Footage 0 PRESENT OPERATION= CIRC MUD ABOVE PLUG DEPTH INCLINATION i ! i AZIMUTH VERTICAL DEPTH BIT INFORMATION NO. SIZE 15 8.5 TYPE STC MFDSSHR S/N LT4853 INTERVAL JETS IN OUT FOOTAGE 3X16 9662 CONDITION REASON HOURS T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.6 VIS FC /2 SOL MWD SUMMARY INTERVAL TO TOOLS 264 PV 10.5 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 o DEPTH: 9662 2/24/01 37 YP 34 FL Gels OIL 69% MBL pH GAS SUMMARY(units) HIGH LOW DITCH GAS 108 @ 9662 16 @ 9662 CUTTING GAS @ @ CHROMATOGRAPHY(ppm) METHANE(C-I) 22026 @ 9662 TRIP @ 0 ETHANE(C-2) 27 @ 9662 GAS @ 0 PROPANE(C-3) 0 @ 0 0 @ 0 BUTANE(C-4) 0 @ 0 0 @ 0 PENTANE(C-5) 0 @ 0 0 @ 0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY CEMENT AVERAGE 55 CURRENT AVG ftJhr amps Klbs RPM psi 43/46 CL- Ca+ 30000 CCI TRIP GAS= 106 WIPER GAS= 0 SURVEY= 0 CONNECTION GAS HIGH= 0 AVG= 0 CURRENT 0 CURRENT BACKGROUND/AVG 18 GAS DESCRIPTION Il ' ' I II I DAILY ACTIVITY RIH & SPOT CEMENT PLUG @ 10025', CIRC & COND MUD, POOH FOR HWDP, TIH TAG PLUG @ 9662, CIRCULATE OUT SUMMARY WELL & COND MUD, 108 U TRIP GAS. Epoch Personel On Board= I Daily Cost $2075 Report by: LEES F. BROWNE JR.
