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Home My WebLink About192-094CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: H2S on P1-20L1 Date:Saturday, May 7, 2022 2:39:15 PM PBU P1-20 (PTD 1920940); prep to cut window in P1-20 to drill lateral L1. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Mark Igtanloc <Mark.Igtanloc@hilcorp.com> Sent: Saturday, May 7, 2022 1:30 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Monty Myers <mmyers@hilcorp.com> Subject: H2S on P1-20L1 Mr. Regg Yesterday at about 13:30 while prepping to run in the well for our initial run for a bottoms up well kill, we got some H2S at the shaker. Below is the detailed information of what happened Our first run in the well we were going to pressure deploy our Milling BHA, RIH and circulate a bottoms up with KCl then swap to drilling mud to mill the window. When we opened up to the well to a closed swab, the well head pressure on the manage pressure line was just under 600psi. The day before it was only 75 psi so the well had swapped to a gas cap. The master valve was shut in and the decision was made to stand back the milling BHA that was in the pressure deployment lubricator because we don’t have a good way to purge gas out of this 72’ long lubricator, make up a nozzle BHA, RIH and perform a bottoms up kill. We made up the nozzle BHA, stabbed on the well the, the driller lined up to pump 15 bbls of methanol into the coil for the trip in the hole. The returns were lined up to the tiger tank outside then after a few bbls the returns cleaned up and were brought inside. After pumping a few more bbls of water the low level H2S light started flashing and the display showed 12 ppm H2S. The returns were sent back to the outside tiger tank and we monitored the display on the H2s Panel. The PPM slowly climbed up to 20 ppm where the alarm sounded and we instructed all personnel to muster at the primary muster area. The PPM got as high as 23 ppm then as we were leaving the ops cab saw that they had dropped to 18. We evacuated and made notifications to the pad operator, Safety Officer and Drilling Manager. The crews were cleared to go back on the rig after levels were checked, the display was still showing 10 ppm at the shaker but 2 hand held gas monitors were showing 0 PPM. The sensor was replaced and retested before we continued our operations. Mark Igtanloc Sr. Drilling Foreman – CTD Rig (907) 670-3097 Cell (907) 268-9140 Positional Email AlaskaNS-CTD-DSM@hilcorp.com Alternate: John Perl Hilcorp Alaska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CDR2-AC BOP Schematic &'55LJ V'ULS3DQ )LOO/LQHIURP+) 1RUPDOO\'LVFRQQHFWHG +3KRVHWR0LFURPRWLRQ +\GULO $QQXODU %OLQG6KHDU 3LSH6OLSV 3LSH6OLSV 3LSH6OLSV N0XG &URVV 3LSH6OLSV 3LSH6OLS +) QQHFHHHHHHHHHHHHHHHHHHHHHHHHHHHHHHHHH v, or T4 ,0, 1//7",s, THE STATE Alaska Oil and Gas � �, of ® sKA Conservation Commission _ � 333 West Seventh Avenue 0.14, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS _._ Fax: 907.276.7542 www.aogcc.alaska.gov David Wages Well Interventions Engineer BP Exploration(Alaska), Inc. SCANNED 0-1-3 1 5 7fl PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P1-20 Permit to Drill Number: 192-094 Sundry Number: 317-548 Dear Mr. Wages: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, f9t2,44,414"-- Cathy . Foerster Commissioner DATED this /4 day of February, 2018. RBDNSFEF - L18 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �� o�� 20 AAC 25.280 �/ 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 8 S z'Repair Well ❑ `t` 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Chane ..rov-. gram 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number. 192-094 " • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0 99519-6612 Stratigraphic El Service 0 6. API Number 50-029-22288-00-00 ` 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU P1-20 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028297 ' PRUDHOE BAY.PT MCINTYRE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10500 • 9453 • 9080 8192 9080.9699 None Casing Length Size MD ND Burst Collapse Structural Conductor 78 20" 42-120 42-120 1490 470 Surface 3433 13-3/8" 41-3474 41-3474 3450/4930 1950/2260 Intermediate 9596 9-5/8" 40-9636 40-8667 6870 4760 Production Liner 1006 7" 9493-10499 8538-9451 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9264-10056 8341-9049 4-1/2"12.6# 13Cr80 37-9691 Packers and SSSV Type: 4-1/2"Baker Model D Packer Packers and SSSV MD(ft)and ND(ft): 9136/8237 4-1/2"Baker SABL-3 Packer 9267/8343 4-1/2"Cameo TRDP SSV 1993/1993 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: December 15,2017 15. Well Status after proposed work: Oil Il WINJ El WDSPL El Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wages,David be deviated from without prior written approval. Contact Email: David.Wagesi bp.com Authorized Name: Wages,David Contact Phone: 907.564.5669 Authorized Title: Well Interv- tions E.=P eer / (�( Authorized Signature: Date: C0 // 7 COMMISSION USE ONLY/ Conditions of approval:Notify Commission so that a representative may witness Sundry Number: l/�' Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ID Location Clearance CI 3 n, " Other �/ Post Initial Injection MIT Req'd? Yes 0 No IJ Spacing Exception Required? Yes❑ No iB Subsequent Form Required: / ) — 4o/ 0,7 /� „),,,,..s..,,,,, APPROVED BYTHE Approved by: /✓ COMMISSIONER COMMISSION Date:2../d-_/4g / G `/300/e T cru )2////7 ORIGINAL RPE.M.I's IL Fri - I Lots Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS i Before me, the undersigned authority, on this day personally appeared Dc,u 1(�1 fL e5 , who being duly sworn states: 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration(Alaska)Inc. ("BPXA")and I am familiar with the Application for Sundry Approvals to stimulate the P1-20 Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On August 28th, 2017, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 28th day of August, 2017. (Signature) STATE OF ALASKA THIRD JUDICIAL DISTRICT Subscribed and sworn to or affirmed before me at A&C,h-4(% Date: August 21, 2017 Subject: P1-20 Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: AOGC Commission /lf 43'1 4' Attached is SP's proposal and supporting documents to fracture stimulate the Kuparuk interval of well P1. 2,-3,.> P1-20 is offset to P1-07 parent wellbore which is a great producer in the Kalubik formation in 1993 and there is enough log evidence to suggest the sand exists in P1-20 and is likely oil bearing. This S,,tio ger/ was verified on December 28th, 2016 where initial test through the portable test separator showed %c., /.34:47 encouraging oil/water rates. The well was then shut-in since the well had no flowlines. A work order 3(7 Oeb was placed to unblind the well and after some time, the well was unblinded and back into service in p ‘60e2t. July 2017. There is a fluctuation in WC due to separator issues but a shake-out back in July showed very little water. This looks like a prime candidate to frac this interval due to the OOIP and only one 1.51'3 ? offtake in P1-07. The other is better conductivity through the wellbore since the perforations were • through 3 strings of pipe. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which requires identification of fresh ""4`" water aquifers and a plan for basewater sampling. We are also requesting that the requirements in • section 20 AAC 25.283, a, 10 be met by pressure tests of the tubulars on the well to be stimulated — ' and by investigation into the mechanical condition of the wells within ' mile of the wellplan within the producing interval. Please direct questions or comments to David Wages / V7 Affidavit of Notification (20 AAC 25.283,a, 1) Partners notified 8/28/2017: ConocoPhillips ExxonMobil Chevron Department of Natural Resources Plat Identifying Wells(20 AAC 25.283,a,2,A-C) and Faults(20 AAC 25.283,a, 11) .70400 671200 672000 672800 673600 674400 675200 676000 P1 12 TKO TKLB -1 )I P1 21 diPt - Tr B Ii '1 P1-0 ., Tesraee #auk -411i . " 1 4:0001,1(7 ,i,,,,....r_lli44IllIlIllIliillIlliiihh, /111111111416, \I 1 f ' .70400 671200 672000 672800 673600 674400 675200 676000 0 500 1000 1500 2000 250181US 1 112000 Green lines indicate approximate length and location of the frac. Producers within 'h mile of P1-20: P1-12 P1-18 P1-18a P1-07a Per the plat above, there are no water wells within 'h mile of the subject well. The above map shows 1 primary fault of concern: Fault #1 which is approximately 1000' away from P1-20's wellpath and —800' away from the max expected frac length. If a sudden change in pressure is seen during the fracturing treatment indicating connection to the fault, pumping operations will cease. Exemption for Freshwater Aquifers(20 AAC 25.283,a,3-4) Well P1-20 is in the East Operating Area of Prudhoe Bay. Per Area Injection Order No.4 dated July 11, 1986 where ARCO (BP) Alaska requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids. Finding #5 specifies that: "Within the Project Area, injection into, V though, or above fresh water aquifer or underground source of drinking water will not occur." To comply with this finding, the operator must confirm integrity of the well that will be injected in per the injection order and the integrity of wells within 1/z mile radius per 20 MC 25.283. These requirements will be met and proven in this document, thus allowing BP exemption from 20 AAC --"'�-14`''"r 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283,a,5-6) Well P1-20 was spudded on 10/8/1992. The 30" surface hole was drilled to 3500' where 13-3/8" 68#, K-55/L-80 surface casing was set and I pair cemented with 1500 sx of 'E' perm cement and 400 sx of 'G' cement, the plug was bumped © 2000 itft� psi 9 i The 16" production casing hole was drilled to 9637" where 9-5/8" 47#, NT-80 production casing was . Zp set and cemented with 740 sx of class 'G' cement. Plug was bumped with 2000 psi. The 8-1/2" production liner hole was drilled and cored to 10,500' where 7" 26#, 13Cr-80 was set and 9 cemented with 211 cu ft of Class 'G' cement. PBTD: 10,408' 12/2016, Perforate Kalubik, install IBP and stop /t-517 Accurate Pressure Ratings of Tubulars and Schematic(20 AAC 25.283,a,8) TfR� Fh4t'; ViaLrEau_ qyY SAFETY NOTES:TUBING HANGER:RAC N 0 ACTUATOR OTIS'': P 1 -2 0 I 22"MD.4-112'CHR TB0 8 7"CHR LNR KB.13EV- 550.8''1 BF ELEV= „.,„„„.,., , ....M D KOP= 39/f 1683' I--{4.tY7'c.AMCOTat7P sssV =3.617 ' /Au Angle.. 38" 8869 GAS LFT I,MF43RH_S QatumND= 9838' ST NO TVD CEVTYRE VLV LATCH;FORT DATE Datum TVD= 8830'SS 1 3538 3537 2 TGPO DOAN TG 16 11111/11 2 5680 5477 36 TGPO SO TG 22 11111111 13-318•( G 688.K-557 B0,D=12.34T — 3500- 3 6889 6447 36 TGR) DAY TG 0 01/03/93 4 7542 6971 37 TGF) CONY TG 0 0/03/93 Minimum =2.00" 9080' 5 8273 7554 38 TOP) 1841 RK 0 11711711 4-112"IBP STOP ON X LOCK 6 9040 8160 38 TOP) CIA/ TG 0 01/03793 FAODUCT7ON MANCRB.S ST ND TVD DEV TY FE VLV LATCH PORT SATE 7 9186 8277 36 MED CONY TG 0 0171753 8 9441 8492 29 MR) CV( TG I 0 01/03/93 9 9474 8521 28 TGF) GAY TGE 0 01/17(93 t 7 9080' H4112"SINS RP,ID=3 813' » 94)817 ...I-4-17T NS f PSTOPe/x LOCK j (12/77/16).D=200' 4At•Y b f)1•QA Ili:R n isle, .- tf•4.75" 1 _ I 9161' 14.11T SIS Pp D=3.813" ........ L ( i"a' H ,Fa�DET3usrFs s(s24t 4Sa) Rpm r LMt 9506' I I ' —' 9620• TX4-V7 BAKER SASE3 PEA.D=3.67-,,.I • 9-58'CSG.470,NT-80,L1-8.691'H 9631 —� ' 9661" j 4117 SYMS NIP D=3.813` e trr TBGt�8F13-CRTISCT..6152 bet.ID-3.958'I--I 6686' j RET4`ORAINN smokily \\\\\ 1 1 9673" 1-14-17?SYM/NP.D=1725' FIEF LOG DLIGR ON 10/29/92 , gyj' 4 112 TU81YC TAE,ALM,C=3.95- ANGLE ATTOP FINE'32"09264' Lsaw 7-.1B.MOTTLOGGED 01/22/93 Nate-Refer to Production OH for hialortal,ter!data SIZE SFT NTERVAL Opn/Sgz DATE 19699 H3-3,8"'ELIA 3.716-BAR 69')12)25/18)1 -3 3/6 4 9264 9310 • 0 01704/93 2-718' 6 9599-9613• 0 12/75716 2-78' 6 9616-9620• 0 12725/16 2-718' 6 9630-9643. 0 12725/16 3-378' 6 9735-9775• C 05/23/04 3-318" 4 9795-9662 C 01/23/93 74-794' 4 !7971-96175. C. nu22793 3.38' 6 9880-9890• C 0523/04 3.316' 6 9920-9950- C 05722/04 3-38" 6 10005-10025. C 05/22104 3-376' 6 10035-10055• C 05722/134 3.38' 4 10036-10056• C 01122/93 I IB'1f) 7W09' 1101!1114 ►00011/11 I r LW,289,CR-13-80.0383 bet,D=8276' 10sc0" LI9414!1 DATE TTG/DY COM ONTS DATE I REV BY COM.84RS PRLUVE8AY 4.941 01/06793 018 ORIGINAL COMPLETION 12/29/16JU.RO AMINES/SET IBP(12725116) WE.:P1-20 5722-5/23704 MJAIKK ACI•ERFS 12/29/16 ZV/JND SET I13PSTOP(12127/18) WRIST No''1920940 08104/04 GR CERP SURF CSG CCRREC 93N AR No 50 029-2228&00 05/29/16 OFT4'OTM CSC CORRECTIONS 111)24/04) SEC 16,runt R14E,1364'FSL 8 908'FEL 10/28111 fAAFJNU GLMC3F/1ECT10►S(10112111) 11714111 N6&PJC GLV 070111111111) rP Brplorallon(Alaska) Name/Size Weight Grade ID Burst, psi Collapse,psi 13-3/8" Surface Casing 68# K-55/L-80 8.835 3450/4930 1950/2270 9-5/8" Production Casing 47# NT-80 6.184" 6870 4760 7" Production Liner 26# 13Cr-80 6.276 7240 5410 4-1/2" Production Tbg 12.6# 13Cr-NSCT 3.958" 8430 7500 Wellhead: FMC manufactured wellhead, rated to50OOpsi. Tree: 4-1/16" 5'800pai Tubing head adaptor: 11^ 5i000poix4-1/16^ 5,000poi Tubing Spool: 11^ x13-5/8^ 5.O00psiwy2'V1G'' side outlets Casing Spool: 1315/8^ 5,0O0psiw/2-V18^ side outlets Geological Frac Information (20 AAC 25.283,a,9) Formation MD top TVDss top TVD Thickness Frac.Gradient Lithological Description THRZ 9492 -8486.5 83.17 0.7 Shale TKLB 9585.22 '8569.67 15.12 0.63,Sandstone/silt TKUP 9601.92 '8584.79 122.45 0.6 Sandstone UCI 9736.14 8707.24 92.94 0.61 Sandstone U84 8838 880C13 56.19 0.61 Sandstone UB3 9899'67 8850.37 28.49 0.62 Sandstone UB1-2 9930.97 0384.86 79.51 0.03 Sandstone U41'4 10018.5 -8964.37 53.16 0.66 Sandstone LC3 10077.09 '9017.53 181.38 0.65 Sandstone LCI I0222 '9I40.91 48.01 0.64 Sandstone LB1 10275 9156.92 104.67 0.63 Sandstone TMLV 20390 9301.59 0.63 Sandstone Mechanical Information of nearby wells(20 AAC 25.283,a, 10) Well Name Caste Type Casing Size Casing Depth Hole Size Vol cmt TOC est.via TOC TOC Top of pay interval Zonal Isolation? Comments Inches Feet Inches Cu Ft MDFeet TVDssFeet 7VDssFeet P1-12 pc Production Casing 9625 9591 12.25 440 Volumetric 8509 7410 8562 Yes P1-12 p1 Production Liner 7 10399 8.5 241 Volumetric 8936 7772 8562 Yes Fully cemented liner P1-18 pc Production Casing 7 11264 8.75 266.8 Volumetric 9897 8738 8573 Yes Well has been P&A'd P1-18a pc Production Casing 7 10623 8.75 454.25 Volumetric 8296 7331 8468 Yes P1-07a p1 Production Liner 7 10644 8.5 377.2 Volumetric 8354 7253 8611 Yes Summary Hydraulic Fracture Program (20 AAC 25.283,a, 12) (Detailed program included) Hydraulic fracture treatment schedule stage 1: FLUID PUMP CF DIRTY VOLUME PROPPANT CLEAN VOLUME fMaps. Finn PUMP TIME SEEP STAGE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM STAGE CUM STAGE CVM sOE mass CUM Breaker Cone. STAGE CUM S 4 PPA (BPM) 18PM1 (081) (BSL) (GAL IGAU ILBES (LSS) OWU MBP MASA (MMPI) 1M6.) OBBL) 4 + PAD YF128F1ex0 40 203 100 371 4200 15582 0 2000 9 100 371 8.0 00:0230 00'0016 j s + 0.5 FLAT W12851000 40 391 200 _-- 571 8400 23982 4109 6,109 16,30 Sana 196 567 8A 0010600 00-14-16 6 1 PAD YF128FIexD 40 40.0 100 671 4200 29182 0 6,109 MO 667 80 00.02:30 00:16,46 1 7 1 1 PUT 91128Flexl) 40 38 50 721 2100 30282 2011 8.120 16120 camoLoe 48 715 8A 00.0115 00:1801 ! s f 7 wMP YF128FIexD 40 38 38 759 1575 318.57 7508 9.628 lsrzac rboL u• 36 750 8A 000056 001857_) ..__s _ + ...... 2 wow YF128FIex0 40 36 38 796 1675 33432 2894 12 522 15,20 Carlon.. 34 785 BA 00:00--56 081953 1 to + 3 SAW W1288160 40 36 3 38 834 1575 35007 4171 16694 16020 Cadonne 33 810 8.0 00:0006 0820:491 11 1 4 rumW YF128F1490 40 34 1 38 871 1575 36582 5353 22.046 16120 Carbelire 32 856 8.0 00-0006 0027-45 ..... fx + .._......_5 BMP YF128F1400D 40 32 3 38 909 1575 38157 6448 28 495 16120[,naLne 31 881 10.0 0000:66 0022'01,j 13 I 6 sAMP YF128FlexD 40.,,...,_31 E. 38 946 1676 39732 7468 35962 1n20 corbel.__ 30 910 10.0 00:0056 0023:37 j ._ a (..,.,..,_ 7 now YFt26Fk D 40 30 38 9U 1575 41307 0118 34 380 6¢0 ramal. 29 939 10.0 00.00:56 00-2432 1 %__._.__..+ 8mow YF128FlexD 40 29 ... 38 .._ 1021 1575 42882 9306 3 636 neL 28 967 10.0 00 .56 002529i - - ._.,- 4 15!20 C ._...___1s1z0 camaBaaa 37 10 0 ......_.____. _..._.:3 1B + ...____8exD 40 29 FLAT YF128FI1077 1!982 12408 66094 03 10.0 00:01.15 0026:444 ! ..._ 50 2100 __. __.... t7 1 9 FLAT YF728FIexD 40 28 6 50 1121 2100 47082 13517 79.6112 16020c,noeaa 36 1039 100 000115 002759' ss ....---1----,710 FLAT YF128Fle D 40 27 7 50 1171 2100 49182 14569 94 170 15,20 c eo0ond 35 1074 10.0 00 01 15 00 2914 ! I, + 11 FLAT YF128FlexD 40 269 25 1196 1050 50232 7769 101 939 1m120C novo a 17 1091 100 00:0037 0029.51 j m + 12 FLAT Y512851000 40 26 1 25 1221 1050 51282 8230 110.169 16120 CaabeGand 16 1107 10.0 00.00 37 003028 1 857 a f FLUSm WF128 40 30 0 108 1329 4516 55798 110.169 108 1215 0.0 06.02 41 00 3309 157 ...a num Freezeprot a 15 15.0 33 1362 1406 57204 _ 110..169 --_ -.. 33 1248 __ _ 00 02:13 _00 3522 TOTALS 1362.. -.- _-110169 1248 _._ 0035-227 The induced fractures are expected to propagate at 30 degrees west of north. Maximum Anticipated Treating Pressure:4500 psi Maximum Allowable Treating Pressure: 5000 psi Surface pressure is calculated based on a closure pressure of -0.64 psi/ft or -5500 psi, this combined with the anticipated net pressure to be built, hydrostatics and the friction gives a maximum surface pressure of 4500 psi at the time of flush. Anticipated half length: 250' ' Anticipated height growth: 80' ' The above frac dimensions were calculated using modeling software. Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values, the above half length is calculated. The frac height is primarily based on closure pressure differences between the confining shale layers and the unconfined sandstone reservoir. Average confining layer stress is anticipated to be -0.7 psi/ft. Prior to fracturing operations, service coil (or slickline) will plug back to prevent a re-frac of old perforations. The target perforations are from 9599'-9643' Pressure Test Information (20 AAC 25.283,a,7) Per the fracturing program, the both the tubing and the IA will be pressure tested. The IA will be tested to 3500 psi and the tubing will be tested to 3500 psi. The wellhead will be tested to 5000 psi, a tree saver will not be required. PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 5000 psi Stagger Pump Kickouts between: 4500 psi and 4750 psi (90%to 95%of MATP) Global Kickout: 4750 psi (95%of MATP) IA pop-off set pressure: 2700 psi (<75%of MIT-IA) Treating line test pressure: 6000 psi 48,000# 16-20 Carbolite, 57,000# 16-20 Sand Requirement CarboBOND, 3000#20-40 or 16-30 sand Minimum Water Requirement 1800 bbls (pump schedule: 1400 bbls) IA Hold Pressure 2300 psi (IA pop-off @ 7 oOpsi) OA Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. rP1-20 Rig Up1 vrlsek®.e 'Timesaver mooted cmvrel TA PIM Ismer Annukur Dessitoeseter Ce pump forL4pireesure �' Boom control 111.111111411. Bes Frock / Prop Fad Dump L _ J Chemical Disclosure (20 AAC 25.283,a, 12) C writ 5P Er ph:-anon.15:.3 SehlUMberger Wel. Basin/held: P....2i: Prucl ice 53. State: Alaska Couritp/P-arish: North Dope Borough Case: Disclosure Th.pe Pre-.ob Well Competed: Date Prepared sinizor?9:05 PM Report 4: RPT-50546 Fluid Name&Nalame Athirtive &dative Discription Concentratim Volume 8534 Tern porart Clay Stabil oar 2.1 Gal/1000 Gal 110.0 Gal ... f112 SurfaCtNat 1.1 Gal/1000 Gal 60.0 Gal J218 Breaker 2 Lb,1000 Gal 105.0 Lb 1475 Breaker 7.5 L3;1000 Gal 400.0 Lb J604 Crosslolier 2.5 Gal,'1000 Gal 135.0 Gal 1891 Guar Sitarro 6.8 Gal!1000 Gal 360.0 Gal tr421111ex004F128 53,256 Gal 1065 Scale habbitot 1 Gal/1000 Gal 55.0 Gal M302 Additive 1 b!L1000 Gal 55.0 Lb 1..4330 M300 0.6 Gal"1000 Gal 30.0 Gal 1012-1630 I Propping gent varied concentrations 6120.0 Lb 3125 lc t vator . 3.6 Gal,1000 Gal 30.0 Gal 1522-1620 Propping gent raned concentrations 47,600.0 lb 1526-1620 Propping Anent aned concentrations 56500.0 lb Mr wand mdamle At/nem Wit ladiadan dtamw adeparsdnw.4 ILrnvuttu.naf mu,-Li.1{4A.140 W., , .1,,o,..,i t ir.t CAS Number *avid Move Mass Fraction - *ate!"l inir.Laing Mi.,hater Lupo ied b,..Client:* 66402-68-4 Ceramic matertais and dafin chemicas ''.19% 14808-667 Quartz,Crystal ine silica -1% 64742-47-8 Distillates,pettoleuo,Mdratreatedli08 <1% 9000-30-0 Guar gum 1% . _ 1319-33-1 Umite <I.% 107-21-1 Ethylene GIvr.ol <01% 7727-54-0 Diallitinanning permidisultMate <01% 67-48-1 2-1Ndreopx-0/114-trirneth5lethararnitsten thloride <015 129898-01-7 2-Propenoic acula polymer with sockeephosphinate <01% 67-63-0 Provo-2-cl <0.1% ,.. .... 68131-40-8 Althltiols,c11-15-secoodour ethinvlated <0.1 36 2508-72-6 VitMidem ddorideintethUllathlbelle therilloset <0.1% 7786-30-3 IllagoesMn demi* <01% 7647-14-5 Sorban&Mile <01% 111-304 GlutaraldehMe <01% 130346-4 Seim Tetraboralle Dethbodiale <01% 31726-344 Palvtany1,2-ishanediroll,alphalearki-assesabydrow <01% 1310-73-2 5/11181!.!1! ,............—Orr.Ill qtYl. — 68153-304 aware seated sanectite day <0.01% 10043-52-4 rion climb% <0.01% 110-1741 lowt-a-mosificat acid <001% 68131-39-5 Alcallok C12-15 Door,elhontated <0.01% 76314164 Moon Dioxide <0.001% 61789-77-3 Dirmcordmedayl quaternary ammonium chloride <0001% 14807-966 iiireiiri 11Cate frftkalle .(1#0 <o01% 111-466 2,2"-oranot OmPwitY) <wool 5 ., _ 900244-0 pohttetralhoroettMenej - <0001% 595585-15-2 Detae <0.001% 125005-87-0 Diutan pine <0001% 7447-467 Potassium&Weide,; ,..1„.1) <0.0001% TOta' 1.3.0gt •IN&..war,bsupphirt by elat dime Silikrierpo hot poolfraeri nosingypoi4411hemar r and moo previa.irkedalkekmart a i e tomponste Fat erog,Mot.11.0 adoird sod.avast ph,ollifoliareit. •The erstarogno ortornithed bawler.os prejkormal hateettaa earmongsaaliore 404.1•11.0whorad.....he easel shwa.*samporbitormiNVIsrateduse N.kaapan esreseCithroaindi.we rho gerdie oflitm r agmmone mos pratitited.Aft o an•optima volt woe he traseard dr OA o aorta. Wellwork Procedure Request To: D. Scarpella/A. Bass: Boss-men Date: 9/8/2017 R. Mielke/C. Olsen: Coil and Well Testing Supt. VER1 L. Seymour/ R. Burnett: Well Support Supt. AFE: XXX From: David Wages IOR: XXX Est. Cost: XXX Subject: P1-20 — Pre/Post Frac Procedure Please perform the following steps 1. W Install TWC, test tree to 5000 psi, PPPOT/service wellhead 2 S Drift, Install plug, Pull LGLVs, Install Dummy valves, Circ brine w/freeze protect, install dummy in sta 1, pull plug, Dump bail sand plug 2. F Assist SL MITs 5. F Hydraulic Fracture Treatment 5. CP Contingent FCO 6. S D&T, Install GLVs 7. C Post frac FCO 8. T Post frac flowback Current Status: Operable Minimum ID: 3.725" at @ 9672' MD. 4-1/2" `SWN'-Nipple (likely XN-Nipple as IBP stop sits in X- profile) 2" ID Northern Solutions IBP Stop @ 9080' Max Deviation: -38 deg fr. 5250'- 9150' MD Tbg Tail Deviation: 24 deg at 9685' MD Last TD Tag: 12/2016: SL 10' x 3-3/8" dummy drift, tag @ 10,190 Last Downhole Op: 12/2016, Perforate Kalubik, install IBP and stop e SBHP/SBHT: 3933 psi @ 8800', 9/21/16 Latest H2S: 50 ppm, 7/2017 Program Contacts Contact Phone -Work Phone - Mobile Interventions Engineer David Wages 907-564-5669 713-380-9836 Pad Engineer Katie Burton 907-564-5554 907-360-6002 Pad Engineer Lea Duong 907-564-4840 720-951-7238 Page 1 of 8 Well Summary: P1-20 is offset to P1-07 parent wellbore which is a great producer in the Kalubik formation in 1993 and there is enough log evidence to suggest the sand exists in P1-20 and is likely oil bearing. This was verified on December 28th, 2016 where initial test through the portable test separator showed encouraging oil/water rates. Well was then shut-in since the well had no flowlines. A work order was placed to unblind the well and after some time, the well was unblinded and back into service in July 2017. There is a fluctuation in WC due to separator issues but a shake-out back in July showed very little water. This looks like a prime candidate to frac this interval due to the OOIP and only one offtake in P1-07. The other is better conductivity through the wellbore since the perforations were through 3 strings of pipe. History: Pre-2010: issues getting to TD b/c paraffin at —900' and issues getting TRSSV open. Early PPROFs indicate most flow coming from perfs at —9900' 12/2016: 3.84" No-go w/flapper checker to 1959', SSSV open Drift 10' x 3-3/8" Dummy Guns w/ bailer to 10,190', tagged bottom. 12/2016: Set IBP @ 9705', Perforated Kalubik, set Northern Solutions IBP Stop Chart b 409 o 1.) ; • 3997 7,- 7.200 r • - • • - 2010 201 2012 2013 2014 2015 2015 2017 -41-Oil Vols obis) f Water Vol iads9h-Gas Vol ms-c f an-L,neIO-Lne 1/2017: TIFL Passed Objectives: • Frac and pop P1-20 1.1 Critical Issues: Latest MIT-T: N/A, MIT-T required Latest MIT-IA: N/A, MIT-IA required Latest Caliper: 2/1/2016, tubing OK. There is buildup on the ID of the tubing from 9400' down. Page 12 of 8 Procedure 1. Wellhead- PPPOT/service wellhead a. Have Wellhead crew service the wellhead and tree. b. Install TWC c. Pressure test tree to 5000 psi high i. The tree is the weak point in the system during the frac and will determine our max treating pressure d. Pull TWC 2. Slickline- Drift, Install plug, Pull LGLVs, Install Dummy valves, Circ brine w/freeze protect, install dummy in sta 1, pull plug, Dump bail sand plug a. Drift to IBP stop b. Install plug in X profile at 9161' i. X-plug rated to 4000 psi from above ii. Reservoir pressure below plug @ 8260' = 3695 psi iii. Pressure applied from above: (4000 MIT-T) +.44psi/ft*8260' = 7634 psi iv. Differential across plug = 7634-3695 = 3939 psi c. Pull LGLVs d. Install Dummy valves in stations 1-5 per WBD. e. Circ Inhibited Brine, freeze protect with crude or diesel to 2500' in the tubing and IA. i. Total volume (tbg+lA) to bottom station is 622 bbls ii. Freeze protect volume to 2500' is 171 bbls (tbg+IA) iii. Lead with crude/diesel spear f. Dummy Sta 6 g. MIT-T to 3500 psi target i. Max Applied pressure: 4000 psi ii. Do not hold pressure on the IA during MIT-T h. MIT-IA to 3500 psi target i. Max Applied pressure: 4000 psi ii. Do not hold pressure on the tubing during MIT-IA NOTE: It is OK for final pressure to drop slightly below the target pressure if MIT criteria is met. The frac crew can reduce Max treating pressure if necessary. If it does, please note in AWGRs and advise Special Projects i. Pull X plug j. Dump bail 20-30' of sand on top of the IBP i. 7" 29# casing requires 22.2# sand/ft to fill. ii. Total sand requirement should be 440#-660# sand (plan on 500-600#s dumped) Page 13 of 8 iii. Note that the frac crew can place this plug if necessary Fullbore-Assist SL with circ and MITs 3. Special Projects- Hydraulic fracture treatment NOTE: If Slickline did not dump bail sand, the frac crew will place the sand volume during the injection test/DataFrac. a. Frac well per pump schedule Pressure testing Maximum Allowable Treating Pressure: 5000 psi (or WH test pressure) Stagger Pump Kickouts between: 4500 psi and 4750 psi (90% to 95% of MATP) Global Kickout 4750 psi (95% of MATP) IA pop-off set pressure 2600 psi (75% of MIT-IA) Treating Line Test Pressure 6000 psi 48,000# 16-20 Carbolite, 57,000# 16-20 Sand Requirement CarboBOND, 3000# 20-40 or 16-30 sand Minimum Water Requirement 1800 bbls (pump schedule: 1400 bbls) IA Hold Pressure 2300 psi (IA pop-off© D09.Q psi) OA Monitor and maintain open to atmosphere 4. Pending Coil- Contingent FCO a. See Appendix A - CT Screenout FCO Procedure 5. Slickline- D&T, Install Generic LGLVs a. D&T b. Install Generic LGLVs i. This step can be moved to after the post frac FCO/millout if sand top is expected to be above the sleeve or if a hard screenout occurred. 6. Flowback a. See Appendix B - Test Separator Additional Flowback Procedure Page I4of8 Appendix A - CT Screenout FCO/Millout Procedure i. This is a generic FCO/millout procedure for a post screenout FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the event. ii. The objective of this procedure is to get the well cleaned to continue frac operations or to prep the well for POP. iii. Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure b. MIRU CT c. MU BHA. d. RIH down to estimated sand top and begin cleaning out with slick 1% KCL. e. Continue down to —9164' CTMD. At this point we are 100' above the uppermost perforations. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the perforation. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. f. Slowly continue to clean out until returns fall off to —80%. If returns are still good even after the nozzle is past the sleeve (not likely but possible), continue to clean out to IBP i. If returns are too low, it may be necessary to pull the IBP after LGLVs are installed while the well is flowing. g. Once IBP is clear of sand, RIH and pull IBP. h. FP to 2500'. i. RDMO. Page 15 of 8 Appendix B - Test Separator Additional Flowback Procedure 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1%, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. Page 16 of 8 Current WBD: TREE- FMB SAFETY NOTES:TUBING HANGER:IMC IV Eg NEIJ_VIEAD= CEN ACTUATOR- OTIS P 1 -20 2r Ma 4-112'CHR 7BG&7"CHR LNR KB REV 50.8 H = II KOP= 39/f 1983 HZTFCAPIICO TRW ssiv,6;111i ILMx Argle 36° 6869 0 GAS LEFT MANDRELS Cetum 613- 9838 ST 60 NO CEV TYPE VLV LATCH FORT DATE, Datum TVD= 8800 55 1 3538 3537 2 TGR3 COME TG 16 11/11/11 A di 2 5690 5477 38 TGFD SO TG 22 11(11/11 13-3 CC,68K,K-55/1 80 -17 3.4T — 3600* h3 6669 6447 36 TGR) CON TG 1 0 01/03093 Minimum 10=2.00" 9080' 4 7542 6971 37 TGR) CV/ TG 0 01/0393 5 8273 7554 36 TGFD CV/ RK 0 11(11/11 6 90408154 38 TGR) DAY TG 0 04/03193 4-1/2"IBP STOP ON X LOCK FRC/CAXTON 141.143RES ST RID ND C8/ TT PE VLV LATOI PORT ITE 7 9186 8277 36 TOED DAV TG 0 01(17193 8 9441 8492 29 TGR) COM TG 0 01/03/93 9 9474 8521 28 TGPD [PAY TGE 0 01/1793 rV 90604 1.7 SW S PIP,ID•3 813" 4 1i • (121771181 1).2 00' 041o. 1—rii 401.V I I a•Imo n rafeig. I 9161' 1--i4-1,7 SIAS Fir,13.3.817 92E1' 1--1111' FBUL BLASI REIG5(9261-9313') TOP OF LNR 9506' 1 I I • 7 962-F—HT X 4-ier BAKER SA8L-3 PKR,CI=1 87' I I 9-98"MG,476,NT-80, 8 691" H 9637' 9661' —4-10'SWS NF,D.3.813 4-1/2-111G.12.0*.13-CRASCT.,0152 Ing. -3.95r j—f 96115' PFRFORA DON St MARY \I 9672' 1—4-1,2'SIAN D 3 725' REF LOG C1L/GR ON 1929/92 I MEW Hi la-TUB! TAL,%ALM,C=3 96^ ANGLE AT TORRE/ 32'2,9264' J 9668' 03_60 TT LOGGED 01/22/93 I Note-Refer to Poducnon[43 for hotoncal 3ert data StZE SW NTERNAL OpnrSoz DATE NMI'ELM 1.1,3"SKR BP(I2/25/118) 3-383' 4 9264 9310 0 01/04/93 2-715' 6 9599-9613 0 17/75/16 2-715' 6 9816-9620 0 12/25/16 2-710' 6 9630-9643 0 12r25/16 3-3/8' 6 9735 9775 C 05/23004 3-3/8' 4 9795-9062 C 01023/93 3-3,1W 4 -CIA75 r. n1D7Fil 3-3/6' 6 9880-9690 C 0923/04 3-3.6" 6 9920-9950 C 05/22434 3-98' 6 10005-10025 C 0922/04 3-318' 6 10035-10055 C 05/22/04 3-3.113" 4 10038-100' C 0102193 1. H 10408' 4114•4401.4 #A11.1110.11041. 17"LER,260:,CR•13-0,0 0381 bat 1E3- 276" 1050(1 [ATE RCV BY COMMENTS M REV BY CCIAENTS PPLEHOE BAY litiT 01/06/93 016 10MGINAL COMPLETION 12/29016 .11../.104) ALFERFSSET 1)P12/25/16) VEL: ro 5/22 5/23,01 MJ414k ADPERFS 12173/16 ZVLIND SET IBP STOP(12/27/16) mine rr,'1920940 08/04io4 'GRDTLP SU4F CSC DORFELTON AR ND 50 029 22288 00 05/29/06 CFRI3TNI CSD CORRECTIONS f 11174o4) SEC 16,T1214.R14E,1304'FSL&908'FE_ 10/20/11 RWAU CU10-0:1;DUNS .1 11114111 MSc F1A GLV (iv EP Biploration(Abolta) Page 1 7 of 8 TubeMove Analysis: i" nig III —g (7/ mt & T •�r _§ g -S is § i 1 t 4w = ss a mI 1 m 11 ' 1 ' lu n)ays (epeuel H Ua0 aoioi �( g • • Xv. 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H LL 9 1- O_a, R Z (V a v Y @ L Y 'O I .. L Y 2 v F' N N 2 Q _2 L -c-a- ' cc O. L) 0 O U(�'f O 0 O 0 0OQ O V c. IC) OG 0 IL) W �1' 0 co r_ r- '9 9' Ol ) Q Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Thursday, December 14, 2017 10:42 AM To: Davies, Stephen F(DOA) Subject: RE: PBU P1-20 (PTD 192-094; Sundry 317-548) You are probably right. If I cannot confirm a correct yield, I use 1.15 as it is sure to be a conservative value. David Wages BP [ AK 1 Completion Engineer 900 E.Benson Blvd 1744c I.Anchorage,AK 99515 Direct: +1.907.564.5699 1 Mobile: 971.3.380.9836 From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Thursday, November 30, 2017 5:07 PM To: Wages, David ' SUM Subject: RN: PBU P1-20 (PTD 192-094; Sundry 317-548) David, I was spot-checking BP's mechanical information for the nearby wells, and I have a question about the estimated top of cement for the production casing in P1-18A. BP's estimated cement volume of 454 cubic feet seems a bit low based on the cementing record for the 7" casing that is reported on the Well Completion Report for P1-18A(190 sacks Econolite, 205 sacks Class G). I wasn't familiar with "Econolite" cement, so I checked the Cement Program in BP's Permit to Drill application for P1-18A. That Cement Program gives the yield for Econolite as 3.24 cubic feet per sack and the yield for Class G as 1.15 cubic feet per sack. So, it seems like the total cement volume pumped should be closer to 850 cubic feet rather than 454 cubic feet. Or have I made a mistake? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent:Wednesday, November 29, 2017 6:48 PM To: david.wages@bp.com Subject: RE: PBU P1-20(PTD 192-094;Sundry 317-548) David, In addition to the information requested below, please also provide estimates for the top of cement for each casing string set in PBU P1-20 and the method used to estimate those cement tops. Thanks, Steve Davies 1 • • Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies,Stephen F (DOA) Sent:Wednesday, November 29, 2017 6:19 PM To:david.wages@bp.com Subject: PBU P1-20(PTD 192-094; Sundry 317-548) David, I forwarded to AOGCC's senior staff your requested priority order for the four BP Sundry Applications for fracturing operations. For PBU P1-20,the highest priority application, please provide the following information: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i)and (ii)states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520,the application must include (2) a plat (C) identifying for all well types (i) each well penetration, if any, within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration. Accordingly,the Area of Review(AOR)for PBU P1-20 encompasses all of PBU P1-20—from TD to ground surface—and not just the portion of the well that is open to the Kalubik and Kuparuk formations as shown on BP's plat that accompanies the application. Please provide a revised plat that displays the AOR as encompassing all lands within%mile of the entire trajectory of PBU P1-20 and provide the required information listed above. Regulation Deficient Information 20 AAC 25.283(a)(10) BP's application currently lists only four wells within the AOR. Please provide the location, the orientation, and a report on the mechanical condition of each well that may transect the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. I will let you know if I need additional information for my portion of the application review. 2 • Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. • 3 • / ?2 -- Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Thursday, December 14, 2017 10:43 AM To: Davies, Stephen F (DOA) Cc: Wallace, Chris D (DOA); Loepp,Victoria T(DOA); Schwartz, Guy L(DOA) Subject: RE: PBU P1-20 (PTD 192-094; Sundry 317-548) I am working to have P1-20 information of all wells returned to you guys today. L-205a next. David Wages BP I AK I Completion Engineer 904E E Benson Blvd 1744&c I Anchorage,AK 99515 Direct. 4 1.9n/5645669 I Mobile 1./13,380.9836 SCANS From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, December 07, 2017 9:32 AM To: Wages, David Cc: Wallace, Chris D (DOA); Loepp, Victoria T(DOA); Schwartz, Guy L (DOA) Subject: FW: PBU P1-20 (PTD 192-094; Sundry 317-548) David, After discussing with AOGCC's senior staff,we all must adhere to a strict reading of the fracturing regulations. Please provide the following information to support BP's application to hydraulically fracture well PBU PTM P1-20: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i) and (ii)states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520,the application must include (2) a plat (C) identifying for all well types (i)each well penetration, if any,within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration." The intent of this regulation is to identify all wells within a buffer zone of one-half mile radius that surrounds the entire P1-20 wellbore trajectory(let's informally call this the "Wellbore Trajectory Area of Review")that are potential conduits for upward migration of fracturing fluids. Examples here are wells Pt Mc 02, P1-07, P1-12, P1-18, P1-21, P1-23, and others,that have lengthy sections of uncemented annular space open between casing shoes and the top of cement for subsequent casing strings. Accordingly,the Wellbore Trajectory Area of Review for PBU P1-20 intended by regulation encompasses all of the PBU P1-20 wellbore trajectory—from TD to ground surface—and not just the portion of the well that is open to the Kalubik formation as shown on the plat that accompanies BP's application. Page 1 of the attached file is an example from that shows the Wellbore Trajectory Area of Review provided by another operator that is in the public record. The entire application by that operator is available for review through AOGCC's online WebLink application at http://aogweb.state.ak.us/WebLink/Browse.aspx?dbid=0. The Permit to Drill number for this particular example is 216-039,and the application is shown on pages 73 through 106 of Well History file 216-039. If you have difficulty navigating to this file, call and I will help you. 1 • • 110 Please provide a revised plat that identifies each well within the Wellbore Trajectory Area of Review for P1-20 and the source of information used to identify each well penetration. Regulation Deficient Information 20 AAC 25.283(a)(10) Regulation 20 AAC 25.283(a)(10) requires: "the location,the orientation, and a report on the mechanical condition of each well that may transect the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory;" The intent of this regulation is to identify all wells that penetrate the confining layers above and beneath the fracturing layer within a buffer zone of one-half mile radius that surrounds the portion of P1-20 that penetrates the upper confining layer,the fracturing layer, and the lower confining layer(let's informally call this the "Wellbore Confining and Fracturing Area of Review").These well-penetrations are potential points of fracture-fluid escape from the fracturing layer. In this instance,those potential escape-points are every well that penetrates the Hue and HRZ shales (the upper confining layer),the Kalubik (fracturing layer) and the Kuparuk and Miluveach (the lower confining layer)within a one- half mile radius of the points where PBU P1-20 cuts through the upper confining layer and reaches TD in the lower confining layer. Page 1 of the attached file is an example from that shows the Wellbore Confining and Fracturing Area of Review provided by another operator, although they call this the "1/2 Mi. Frac Point Radius." BP's application currently lists four production wells within the Wellbore Confining and Fracturing Area of Review (P1-07a, P1-12, P1-18 and P1-18a).The map in my workstation indicates at least five wells penetrate the confining and fracturing intervals within this area, the four wells listed above plus P1-17. In the Sundry Application to fracture P1-20, BP presents only estimated top-of-cement information for three wells(P1-07A, P1-12, and P1-18A). The report on mechanical condition must include integrity testing information along with cementing information for each of these nearby wells (Were the casing strings pressure-tested?When?To what psi? Did the well pass an MIT?If so,when?Cement volume pumped? Brief job summary? Plug bumped? Did losses occur?Cement tagged?Cement evaluation log run? Estimated tops (both MD,TVDSS)? How was each top determined?). Please provide the location,the orientation, and a mechanical-condition report for every well that transects the confining layers within the Wellbore Confining and Fracturing Area of Review. Pages 3 to 5 of the attached file is an example of mechanical integrity information provided by another operator. Their spreadsheet format is ideal for clear presentation of both cement and mechanical integrity information,and it allows quick review. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. 2 • • The map accompanying BP's application displays only the Terrace Fault,a clown-to-the- north normal fault that trends east-southeast. No geological description or discussion is provided. A more detailed discussion is needed, and it should address the following topics: Does this fault stop within the upper confining layer, or does it continue upward into shallower strata? Do any of the wells within the Wellbore Confining and Fracturing Area of Review intersect the fault? If so, at what depths (both MD and TVDSS)?While drilling through the fault, did any of the wells encounter abnormal pressure or loose circulation? If so,which ones? Please briefly describe each incident. Do reservoir pressure data or production/injection data indicate this fault is sealing or porous? Please explain. Based on available information, could the fault serve as a conduit for upward escape of the fracturing fluids? If so, into whichoverlying strata? What monitoring/mitigations measures are planned? Pages 6 to 8 of the attached file is an example of the fault and fracture information provided by another operator. The discussions are clear, concise and, along with the tables provided, and they allow quick review of the required information. Also,the map accompanying BP's application displays only the Terrace Fault, a down-to- the-north normal fault that trends east-northeast. That same map shows a different predicted directional trend for the induced fracture (about 30 degrees east of south). What is the basis for BP's belief that the induced fracture(s)will trend southeast rather than east-northeast? For clarity of the public record from the point of view of future users, each Sundry Application to conduct hydraulic fracturing operations should be complete as a stand-alone document. In other words, all required information should be presented clearly within each application. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent:Thursday, November 30, 2017 4:45 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU P1-20 (PTD 192-094;Sundry 317-548) Steve, If you wouldn't mind giving me a call at your convenience, I would appreciate it. Have questions regarding your note below and past approved sundries (L-200a and P1-23 for example). David Wages BP AK I Completion runnier 900 E.Benson Blvd I 744c I Anchorage,AK 99515 Direct: +7..907.564.5669.I Mobile: +1.713.380.9836 From: Davies, Stephen F(DOA) [mailto:steve.davies©alaska.gov] Sent: Wednesday, November 29, 2017 6:19 PM 3 • • To: Wages, David Subject: PBU P1-20 (PTD 192-094; Sundry 317-548) David, I forwarded to AOGCC's senior staff your requested priority order for the four BP Sundry Applications for fracturing operations. For PBU P1-20,the highest priority application, please provide the following information: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i)and (ii)states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520,the application must include (2) a plat (C) identifying for all well types (i)each well penetration, if any,within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration. Accordingly,the Area of Review(AOR)for PBU P1-20 encompasses all of PBU P1-20—from TD to ground surface—and not just the portion of the well that is open to the Kalubik and Kuparuk formations as shown on BP's plat that accompanies the application. Please provide a revised plat that displays the AOR as encompassing all lands within 1/2 mile of the entire trajectory of PBU P1-20 and provide the required information listed above. Regulation Deficient Information 20 AAC 25.283(a)(10) BP's application currently lists only four wells within the AOR. Please provide the location, the orientation, and a report on the mechanical condition of each well that may transect the confining zones, and information sufficient to supporta determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. • Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. I will let you know if I need additional information for my portion of the application review. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well UGINAI OIL ® GAS 1=1 SUSPENDED 0 ABANDONED SEF1VICE X Completnri 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-94 3. Address 8.API Number P. O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22288 4. Location of well at surface 9. Unit or Lease Name 1384'NSL, 908'WEL, SEC. 16, T12N, R14E, UM t f-`;.7;; �'=,f..�~. LOCATIONS Point McIntyre At Top Producing Interval t 111)-z"•fr VEJ,j D 10. Well Number 792'SNL, 1492'WEL, SEC. 16, T12N, R14E, UM'--4V-05,42, Sur {.-3 P1-20 311. Field and Pool Al Total Depth >_ leffin L H. -.5".17,4 �' 1.6 �"•�+..�.•tr..""4 Point McIntyre 440'SNL, 1475'WEL, SEC. 16, T12N,R i4E, UM--~--:-.......:,.:-j 5. Elevation in feet (indicate KB, DF,etc.) 6.Lease Designation and Serial No. KBE..50.8' ADL 28297 12. Date Spudded 13.Date T.D.Reached -14.Date Comp.,Susp.or Aband. '13. Water-Depth, if offshore 16. No. of Completions 10/8/92 10/28/92 11/1/92 N/A feet MSL Zero 17.Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD)19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafros t 10500'MD/9453'TVD 10408'MD/9369'TVD , YES ❑O ND 0 N/A feet MD Approx. 1750' 22. Type Electric or Other Logs Run Run#1GR/CN/ZDL/DIFL Run#2 MAC/GR 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 73' 30" 11 yds Arcticset 13-3/8" 68# L-80 40' 3474' 16" 3837 cu ft PF"E"/449 cu ft Class G" 9-5/8" 47# L-80/NSCC, 41' 9637' 12-1/4" , 1144 cu ft Class "G" -74 5'V 7" 26# 13CR80 41' 10500' 8-1/2" 211 cu ft Class G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MD) PACKER SET(MD) Not Perforated None 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT&KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not yet on production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD • Flow Tubing Casing Pressure CALCULATEDOIL-BBL GAS-MCF WATER-BBL SOIL GRAVITY-API (Corr) Press. 24-HOUR RATE ff� 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Please see attached core description. S� it .` w I! ,, 3 �� if 7-0 e Cet,/ G f° r - d r o� 1Gl ,. II44 3 2 0 1- bb`S . -2. 9 �Ul vrn r� /. Te Form 10-407 Submit in.duplitt rte-f Rev. 7-1-80 CONTINUED ON REVERSE SIDE !v/ VTC w/ 3i WaSho c = 2/ r^, ' WELL : P1-20 PAGE: 2 OPERATION: RIG : POOL 7 10/16/92 ( 9) DRLG. MW: 9. 8 VIS: 37 TD: 8690' ( 807) DRLG F/ 7883'-7980' . CBU. SHORT TRIP 15 STDS. DRLG F/ 7980'-8690' . 10/17/92 ( 10) RIH W/ LOGS. MW:10.0 VIS: 41 TD: 8895' ( 205) DRLG F/ 8690'-8895' . CIRC. POOH. P/U ANADRIL CDR TOOL. RIH TO 7138' . LOG TO BTM. 10/18/92 ( 11) RIH W/ LOGS. MW:10.1 VIS: 46 TD: 9200' ( 305) RIH W/ LOGS. DRLG F/ 8895'-9200' . CBU. POOH. CHANGE BHA. RIH TO 9120' . LOG TO BTM. 10/19/92 ( 12) POOH. MW:10.2 VIS: 41 TD: 9637' ( 437) RIH W/ LOGS. DRLG F/ 9200'-9520' . RELOG F/ 9490'-9520' . DRLG F/ 9520'-9637' . CBU. SHORT TRIP TO 9176' . CBU. POOH. 10/20/92 ( 13) CLEANING ANNULUS. MW: 10.1 VIS: 38 TD: 9637' ( 0) POOH. TEST ROPE. R/U WOTCO. RIH W/ 9-5/8" CSG. CIRC @ SHOE. RIH W/ CSG. R/U CMT HD. CIRC. PUMP 20 BBLS ARCO PREFLUSH, 50 BBLS ARCO SPACER, 140 SX 'G' CMT W/ .5% CFR-3, 3% ECONOLITE, .4% HALAD 344 @ 11.1 PPG & 600 SX 'G' CMT W/ .2% CFR-3, .2% HALAD 344, .25% HR-5 @ 15. 8 PPG. BUMP PLUG W/ 2000 PSI. N/D BOPE. SET SLIPS. 10/21/92 ( 14) CIRC. MW:10.1 VIS: 90 TD: 9637' ( 0) INSTALL SPOOL. N/U HOPE. TEST ROPE. L/D BHA. M/U BHA. RIH. CIRC @ 9555' . TEST CSG. DRLG FC, CMT, FS, 1' NEW HOLE. CBU. LOT (12.5 PPG EMW) . CIRC. 10/22/92 ( 15) CORING. MW:10.2 VIS: 90 TD: 9656' ( 19) CIRC. DISP WELL W/ 10.2 PPG CORE FLUID. POOH. L/D BHA. RIH W/ CB #1. CBU. CORE F/ 9646'-9656' . 10/23/92 ( 16) POOH. MW:10.3 VIS: 88 TD: 9764' ( 108) CORE F/ 9656'-9705' . CBU. POOH. L/D CORE #1. RIH W/ CB #2. CBU. CORE F/ 9705'-9764' . CBU. POOH. 10/24/92 ( 17) CORING. MW:10.2 VIS: 85 TD: 9865' ( 101) POOH. L/D CORE #2. RIH W/ CB. CBU. CORE F/ 9764'-9823' . CBU. POOH. L/D CORE #3. RIH W/ CB. CBU. CORE F/ 9823'-9865' . 10/25/92 ( 18) RIH. MW:10.2 VIS: 78 TD: 9941' ( 76) CORE F/ 9865'-9882' . CBU. POOH. L/D CORE #4. RIH W/ CB. CBU. CORE F/ 9882'-9941' . CBU. POOH. LID CORE #5. RIH W/ CB. 04 b. 4_ b-, I -F F EI VE l /(7 ,16 J U i2 E Alaska Uif c Gas Cons. Commission1993 Anchorage 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS.DEPTH TRUE VERT.DEPTH GOR,and time of each phase. Colville Group 6990' 6528' HRZ 9491' 8536' Kalubik 9603' 8637' Kuparuk 9651' 8680' Miluveach 10389' 9351' 31.LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed U. Title.Drilling Engineer Supevisor Dale 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 spaces 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 producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". • ry7 3: Form 10-407 Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Friday, February 9, 2018 12:16 PM To: Davies, Stephen F (DOA) Subject: RE: BP's Hydraulic Fracturing Applications for PBU S-129, P1-20, L-205A, S-200A, and S-109 - Information Needed Attachments: P1-20_Frac_Justification_Geology.docx; RE: PBU P1-20(PTD 192-094; Sundry 317-548) Steve, Please see attached the area of review maps information for P1-20.The email is the well list and the review of wells within 1/2 mile of the entire wellbore, a bit above what is asked but we did it at the time to ensure we covered our bases. Please advise if there is any additional information needed. David Wages BPI AK I Completion Engineer 900 E.Benson Blvd 1744c I Anchorage AK 99515 Direct: 1..9O7 64.5669 i Mobile: +1.71.3.380.9K30 From: Sidoti,Todd Sent: Friday, February 09, 2018 10:03 AM To: Wages, David Subject: FW: BP's Hydraulic Fracturing Applications for PBU S-129, P1-20, L-205A, S-200A, and S-109 - Information Needed Todd Sidoti I BPXA Well Intervention Engineer I Office 907-564-5113 I Cell 907-632-4113 I todd.sidoti9aibp.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent:Thursday, February 8, 2018 5:18 PM To:Sidoti,Todd<Todd.Sidoti@bp.com> Subject: BP's Hydraulic Fracturing Applications for PBU S-129, P1-20, L-205A,S-200A, and 5-109-Information Needed Thank you Todd. For BP's five Hydraulic Fracturing Applications under review, I need: 1. S-129 (PTD#210-132; Sundry#318-044): Answers to questions and requests emailed to you on 2/7/2018. 2. P1-20(PTD#192-094; Sundry#317-548): Fault information requested in my email to David Wages dated 12/19/2017;Area-of-Review maps similar to those in recent PBU L-205A application. When I spoke with Carl on the phone on 1/29, he said that BP would provide the info in the next day or two. 3. L-205A(PTD#217-118; Sundry#318-020): I have all of the information that I need for L-205A. 4. S-200A(PTD#217-125;Sundry#317-491): Information requested in my email to David Wages dated 11/28/2017;Area-of-Review maps similar to those in recent PBU L-205A application. 5. 5-109 (PTD#202-245;Sundry#316-444): A revised application per my most recent email exchange with David Wages regarding S-109 (dated 1/14/17)that is attached below. Thanks for your help, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent:Wednesday,June 14, 2017 11:30 AM To: Davies,Stephen F (DOA)<steve.davies@alaska.gov> Cc: Carlisle,Samantha J (DOA) <samantha.carlisle@alaska.gov> Subject: RE: PBU S-109 (PTD#202-245, Sundry#316-444) -Application to Fracture Stimulate-Request for Additional Information Nope, we are looking to get that one back up and runner here in a bit. We've had quite a few issues with our deployment system as you may be aware and feel we've finally gotten things ironed out. I will go over it and submit an application per our most recent approved frac sundry(L-200a). From: Davies, Stephen F(DOA) [mailto:steve.davies©alaska.gov] Sent: Wednesday, June 14, 2017 10:59 AM To: Wages, David Cc: Carlisle, Samantha 3 (DOA) Subject: RE: PBU S-109 (PTD #202-245, Sundry #316-444) - Application to Fracture Stimulate - Request for Additional Information David, Did BP ever make a decision regarding fracture stimulation of PBU S-109? Would BP like to withdraw this particular Application for Sundry Approval? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Sidoti,Todd [maiito:Todd.Sidoti@bp.com] Sent:Thursday, February 8, 2018 2:14 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU S-129 (PTD#210-132) Hydraulic Fracturing Application (Sundry#318-044)-Questions Hi Steve, BP's priorities would be P1-20, L-205 (not listed), S-200A and then S-109. 2 Well Status Well Type P1-01 Operable Water Injector P1-02 Abandoned P1-02A Operable Producer P1-03 Operable Producer P1-04 Operable Producer P1-05 Operable Producer P1-06 Operable Producer P1-07 Abandoned P1-07A Operable Producer P1-08 Abandoned P1-08A Operable Producer P1-08PB1 Abandoned P1-09 Operable Producer P1-11 Operable Producer P1-12 Operable Water Injector P1-122 Operable Ml Injector P1-13 Operable Producer P1-14 Operable Water Injector P1-16 Operable Ml Injector P1-17 Operable Producer P1-18 Abandoned P1-18A Operable Producer P1-20 Operable Producer P1-21 Operable Water Injector P1-23 Operable Producer P1-24 Operable Producer P1-24L1 Operable Producer P1-24L1-01 Operable Producer P1-25 Operable Water Injector P1-G1 Operable Gas Injector FAULTS: BPXA has formed the opinion based on seismic,well, and other subsurface information currently available that there is one mapped fault,the Terrace fault,that intersects the Kalubik interval, and enters the confining zone within one half mile radius of the wellbore trajectory for P1-20. The P1-20 wellbore does not cross the Terrace fault.The Terrace fault terminates below the trajectory of the well.The fault terminates below the wellbore in the HRZ and overlying lower Brookian units above the confining zone. The Kalubik is juxtaposed across the Terrace fault with the Lower Kuparuk formation The Terrace fault terminates in the overlying shales, making it highly unlikely that fluids would escape the confining layer. BPXA has formed the opinion, based on seismic,well, and other subsurface information currently available that the fault near P1-20 will not interfere with containment. 870000 672000 674000 676000 678000 . P1-24L z Pff-11 _ P1-2 PTIV1e iT4121 I _-- i P .p Iftq P112 i_i 0 . P1-.0 - F1-1 P1-0 " %) r + p,„ , ,. .,...., err. 18P - . ,-. P -.0114 1 , pr1IIIIIII11' �'. P1 1 =m•Prirr I V1..: 4ftier PN P1-13 Fault is at the reservoir ilevel,and does not come within %a mile o the trajectory of the, ,•'�— wellbore. P1 22PB1 670000 677000 674000 676000 678000 0 500 1000150020002500ftUS . . IM= M 1.20480 Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Monday, December 18, 2017 3:51 PM To: Davies, Stephen F(DOA) Cc: Wallace, Chris D (DOA); Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Subject: RE: PBU P1-20 (PTD 192-094; Sundry 317-548) Attachments: AOGCC 0.5 mile wells list.xlsx Please see attached map: 670000 471000 672000 5T3OCQ 6114000 615000 5.76000 611000 618000 •1Kl$ Thal t [,1 1 to p i . ilfir . . , br4110,41 Pt , ,,...,, 1r . , , 41111/4 11111111,011, 1 l000tiv4fr '11111, ,,,,,'10711r, ; ; Utio, A ,,,,L6 -Ad t I. lir_ ! _,,,,...4., 610000 611000 61000 673000 611400 675004 676000 617000 616000 0 500 1000 1500 2000 25905US I 187$0 Below are the list of wells within Y2 mile of P1-20 wellplan 1 Well Status Well Type P1-01 Operable Water Injector P1.02 Abandoned P1-02A Operable Producer P1-03 Operable Producer P1-04 Operable Producer P1-05 Operable Producer P1.06 Operable Producer P1-07 Abandoned P1-074 Operable Producer P1.08 Abandoned P1-08A Operable Producer P1.O8PB1 Abandoned P1-09 Operable Producer P1-11 Operable Producer P1-12 Operable Water Injector P1-122 Operable MI Injector P1-13 Operable Producer P1-14 Operable Water Injector P1-15 Operable MI Injector P1-17 Operable Producer P1-18 Abandoned • P1-18A Operable Producer P1-20 Operable Producer P1-21 Operable Water Injector P1-23 Operable Producer P1-24 Operable Producer P1-24L1 Operable Producer P1-24U-01 Operable Producer P1-25 Operable Water Injector Pl-G1 Operable Gas Injector Below is the cement top evaluation: 2 . Well Name Casing Type Casing Site Casing Depth Hole Size Vol trot TOC est.via TOC TOC Top of pay interval Zonal isolation? Inches Feet Inches Cu Fl MOFeetTVDssFeet TVOssfeet P1.01 pc Production Casing 9.625 13295 12.25 14375 Volumetric 9761 6386 8804 Yes P1-01 pt Production Liner 7 14124 8.5 385.25 Volumetric 11785 7513 8804 Yes Fully cemented I P1-02a pl Production Liner 4.5 11403 6 I30 Volumetric 9341 7611 8573 Yes P1-03 pc Production Casing 9.625 11413 12"25 724.5 Volumetric 9632 6797 8738 Yes P1-03 pl Production Liner 7 12744 8.5 345 Volumetric, 11089 7892 8738 Yes Cement Volume, P1.04 pc Production Casing 7.625 11637 9.875 710 Volumetric 9091 7178 8629 Yes P1-0S pc Production Casing 7.625 13825 9.875 801 Volumetric 10953 7502 8678 Yes P1-06 pc Production Casing 7 6023 8.5 1349,Volumetric 0 0 8607 Yes P1-06 pi Production Liner 4.5 12139 6 408.25 Volumetric N/A N/A 8607'N/A P1-07 pc Production Casing 9.625 9471 12.25 1638.8 Volumetric 5442 4964 8622 Yes P1.07 pl Production Liner 7 11098 85 546.25 Volumetric 7781 6708 8622 Yes P1-08a pc Production Casing, 7.625 10193 9.875 756 Volumetric 7482 6946 8480 Yes P1-08e pl Production Casing a5 10900 6.75 0 N/A N/A N/A 8480 N/A Cemented in pia P1.09 ix Production Casing 7 11165 8.5 316.25 Volumetric 9245 7763 8605 Yes P1-09 p1 Production Liner 4.5 14475 6 469.2 Volumetric 10269 8436 8605 Yes P1.11 pc Production Casing, 9.625 12272 12.25 440 Volumetric 11190 8024 8725 Yes P1-lI pl Production Liner 7 12950 8.5 259 Volumetric 11377 8147 8725'Yes Fully cemented I P1-12 pc Production Casing 9.625 9854 12.25, 1121.3 Volumetric 7097 6209 8753 Yes P1.12 pl Production Liner 7.625 10749 8.5 773.95 Volumetric 3005 2752 8753 Yes Cement to Liner 1 P1-122 pc Production Casing 9.625 10687 12.25 0 Log 5510 3300 8023 Yes Verified via Log P1-122 pl Production Liner 7 16324 8-5 0 Log 13630 6630 8023 Yes Verified via Log P1-13 pc Production Casing 7.625 10275 9.875 897 Volumetric 7059 6730 9112 Yes P1-13 01 Production Liner 4.5 11010 6.75 0 N/A N/A N/A 9112 N/A P1.14 pc Production Casing 7.625 11761 9.875 493 Volumetric 9993 7875 8676 Yes P1.16 pc Production Casing 7.625 14546 9.875 522 Volumetric 12674 8115 8833 Yes P1-17 pc Production Casing- 7.625 10518 9.875 633 Volumetric 8248 6986 8598 Yes P1.18 pc Production Casing 7 11264 8.75 266.8 Volumetric 9897 8738 8573 Yes Well has been P. P1-18a pc Production Casing 7 10623 8.75 454.25 Volumetric 8296 7331 8468 Yes P1-20 pc Production Casing 9,625 9637, 12.25 1144,Volumetric,. 6824 6394 8680 Yes P1.20 p1 Production Liner 7 10500 8.5 211 Volumetric 9219 8303 8680 Yes Cement to liner I P1-21 pc Production Casing 7,625 11513 9.875 667 Volumetric 9122 7306 8751 Yes P1-20 pi Production Liner 7 10500 8.5 211 Volumetric 9219 8303 8680 Yes Cement to liner I PHI pc Production Casing 7.625, 11513 9.875 667 Volumetric 9122 7306 8751 Yes P1-23 pc Production Casing 7 13423 8.5 310.5 Volumetric 11538 8003 8859 Yes P1-24 pc Production Casing 7 12470 8.5 442.75 Volumetric 9782 6852 8725 Yes P1-24 p1 Production Liner 2.875-14750 3.25 0 No cement N/A N/A 8725 N/A In zone sidetracl P1-25 pc Production Casing 9.625 , 13817 12.25, 724.5 Volumetric 12036, 6875 8892 Yes P1.25 pl Production Liner 7 14797 83 920 Volumetric 9211 5510 88921es P1-G1 pc Production Casing 9.625 8607 12,25 500 Volumetric 7378 7293 8467 Yes Pl•G1 pl Production Liner 7 8840 8.5 115 Volumetric 8142 7983 8467 Yes Cement to top of P2-55 pc Production Casing 9.625 14787 1225_ 4952 Volumetric 2612_ 2539! 8892 Yes Plug bumped ani I believe the cement top evaluation to be over the top as far as how it compares to what Conoco sent you. If you like,we could have a quick conversation to discuss exactly what we need to submit one last time. I think we are both in agreement, but I want to make sure so as to prevent further delays. David Wages BP I AK I Completion Engineer 900 E.Benson Blvd I 744c I Anchorage,AK 99515 Direct: +1.907.564.5669 I Mobile: +1.713.380.9836 From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent:Thursday, December 07, 2017 9:32 AM To: Wages, David Cc: Wallace, Chris D (DOA); Loepp,Victoria T(DOA); Schwartz, Guy L(DOA) Subject: FW: PBU P1-20 (PTD 192-094; Sundry 317-548) David, After discussing with AOGCC's senior staff,we all must adhere to a strict reading of the fracturing regulations. Please • provide the following information to support BP's application to hydraulically fracture well PBU PTM P1-20: 3 Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i)and (ii)states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520,the application must include(2)a plat(C) identifying for all well types(i)each well penetration, if any,within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration." The intent of this regulation is to identify all wells within a buffer zone of one-half mile radius that surrounds the entire P1-20 wellbore trajectory(let's informally call this the "Wellbore Trajectory Area of Review")that are potential conduits for upward migration of fracturing fluids. Examples here are wells Pt Mc 02, P1-07, P1-12, P1-18, P1-21, P1-23,and others,that have lengthy sections of uncemented annular space open between casing shoes and the top of cement for subsequent casing strings. Accordingly,the Wellbore Trajectory Area of Review for PBU P1-20 intended by regulation encompasses all of the PBU P1-20 wellbore trajectory—from TD to ground surface—and not just the portion of the well that is open to the Kalubik formation as shown on the plat that accompanies BP's application. Page 1 of the attached file is an example from that shows the Wellbore Trajectory Area of Review provided by another operator that is in the public record. The entire application by that operator is available for review through AOGCC's online WebLink application at http://aogweb.state.ak.us/WebLink/Browse.aspx?dbid=0. The Permit to Drill number for this particular example is 216-039,and the application is shown on pages 73 through 106 of Well History file 216-039. If you have difficulty navigating to this file,call and I will help you. Please provide a revised plat that identifies each well within the Wellbore Trajectory Area of Review for P1-20 and the source of information used to identify each well penetration. Regulation • Deficient Information 20 MC 25.283(a)(10) Regulation 20 AAC 25.283(a)(10)requires:"the location,the orientation,and a report on the mechanical condition of each well that may transect the confining zones,and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory;" The intent of this regulation is to identify all wells that penetrate the confining layers above and beneath the fracturing layer within a buffer zone of one-half mile radius that surrounds the portion of P1-20 that penetrates the upper confining layer,the fracturing layer,and the lower confining layer(let's informally call this the"Wellbore Confining and Fracturing Area of Review").These well-penetrations are potential points of fracture-fluid escape from the fracturing layer. In this instance,those potential escape-points are every well that penetrates the Hue and HRZ shales(the upper confining layer),the Kalubik (fracturing layer)and the Kuparuk and Miluveach (the lower confining layer)within a one- half mile radius of the points where PBU P1-20 cuts through the upper confining layer and reaches TD in the lower confining layer. Page 1 of the attached file is an example from that shows the Wellbore Confining and Fracturing Area of Review provided by another operator,although they call this the"1/2 Mi. Frac Point Radius." BP's application currently lists four production wells within the Wellbore Confining and Fracturing Area of Review(P1-07a, P1-12, P1-18 and P1-18a).The map in my workstation 4 indicates at least five wells penetrate the confining and fracturing intervals within this area, the four wells listed above plus P1-17. In the Sundry Application to fracture P1-20, BP presents only estimated top-of-cement information for three wells(P1-07A, P1-12,and P1-18A). The report on mechanical condition must include integrity testing information along with cementing information for each of these nearby wells(Were the casing strings pressure-tested?When?To what psi? Did the well pass an MIT?If so,when?Cement volume pumped? Brief job summary? Plug bumped?Did losses occur?Cement tagged?Cement evaluation log run?Estimated tops (both MD,TVDSS)? How was each top determined?). Please provide the location,the orientation, and a mechanical-condition report for every well that transects the confining layers within the Wellbore Confining and Fracturing Area of Review. Pages 3 to 5 of the attached file is an example of mechanical integrity information provided by another operator. Their spreadsheet format is ideal for clear presentation of both cement and mechanical integrity information,and it allows quick review. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones,and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. The map accompanying BP's application displays only the Terrace Fault,a down-to-the- north normal fault that trends east-southeast. No geological description or discussion is provided. A more detailed discussion is needed, and it should address the following topics: Does this fault stop within the upper confining layer,or does it continue upward into shallower strata?Do any of the wells within the Wellbore Confining and Fracturing Area of Review intersect the fault? If so,at what depths (both MD and TVDSS)?While drilling through the fault,did any of the wells encounter abnormal pressure or loose circulation? If so,which ones? Please briefly describe each incident. Do reservoir pressure data or production/injection data indicate this fault is sealing or porous? Please explain. Based on available information,could the fault serve as a conduit for upward escape of the fracturing fluids? If so, into which overlying strata? What monitoring/mitigations measures are planned? Pages 6 to 8 of the attached file is an example of the fault and fracture information provided by another operator. The discussions are clear,concise and, along with the tables provided, and they allow quick review of the required information. Also,the map accompanying BP's application displays only the Terrace Fault,a down-to- the-north normal fault that trends east-northeast. That same map shows a different predicted directional trend for the induced fracture (about 30 degrees east of south). What is the basis for BP's belief that the induced fracture(s)will trend southeast rather than east-northeast? For clarity of the public record from the point of view of future users,each Sundry Application to conduct hydraulic fracturing operations should be complete as a stand-alone document. In other words,all required information should be presented clearly within each application. 5 Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.comj Sent:Thursday, November 30,2017 4:45 PM To: Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: RE: PBU P1-20(PTD 192-094;Sundry 317-548) Steve, If you wouldn't mind giving me a call at your convenience, I would appreciate it. Have questions regarding your note below and past approved sundries(L-200a and P1-23 for example). David Wages BP I AK I Completion Engineer 900 E.Benson Blvd I 744c I Anchorage,AK 99515 Direct: +1.907.564.5669 I Mobile: +1.713.380.9836 From: Davies, Stephen F(DOA) [mailto:steve.davies©alaska.aov] Sent: Wednesday, November 29, 2017 6:19 PM To: Wages, David Subject: PBU P1-20 (PTD 192-094; Sundry 317-548) David, I forwarded to AOGCC's senior staff your requested priority order for the four BP Sundry Applications for fracturing operations. • For PBU P1-20,the highest priority application, please provide the following information: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i)and (ii)states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520,the application must include(2)a plat(C) identifying for all well types(i)each well penetration, if any,within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration. Accordingly,the Area of Review(AOR)for PBU P1-20 encompasses all of PBU P1-20—from TD to ground surface—and not just the portion of the well that is open to the Kalubik and Kuparuk formations as shown on BP's plat that accompanies the application. Please provide a revised plat that displays the AOR as encompassing all lands within%2 mile of the entire trajectory of PBU P1-20 and provide the required information listed above. Regulation Deficient Information 20 AAC 25.283(a)(10) BP's application currently lists only four wells within the AOR. Please provide the location, the orientation,and a report on the mechanical condition of eachwell that may transect 6 the confining zones,and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of,orientation of,and geological data for each known or suspected fault or fracture that may transect the confining zones,and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. I will let you know if I need additional information for my portion of the application review. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 7 /VII Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, February 8, 2018 5:18 PM To: 'Sidoti, Todd' Subject: BP's Hydraulic Fracturing Applications for PBU S-129, P1-20, L-205A, S-200A, and S-109 - Information Needed Thank you Todd. For BP's five Hydraulic Fracturing Applications under review, I need: 1. S-129 (PTD#210-132; Sundry#318-044): Answers to questions and requests emailed to you on 2/7/2018. 2. P1-20 (PTD#192-094;Sundry#317-548): Fault information requested in my email to David Wages dated 12/19/2017;Area-of-Review maps similar to those in recent PBU L-205A application. When I spoke with Carl on the phone on 1/29, he said that BP would provide the info in the next day or two. 3. L-205A(PTD#217-118; Sundry#318-020): I have all of the information that I need for L-205A. 4. S-200A(PTD#217-125; Sundry#317-491): Information requested in my email to David Wages dated 11/28/2017;Area-of-Review maps similar to those in recent PBU L-205A application. 5. S-109 (PTD#202-245;Sundry#316-444): A revised application per my most recent email exchange with David Wages regarding S-109 (dated 1/14/17)that is attached below. Thanks for your help, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent:Wednesday,June 14, 2017 11:30 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Carlisle, Samantha J (DOA) <samantha.carlisle@alaska.gov> Subject: RE: PBU S-109 (PTD#202-245, Sundry#316-444)-Application to Fracture Stimulate- Request for Additional Information Nope, we are looking to get that one back up and runner here in a bit. We've had quite a few issues with our deployment system as you may be aware and feel we've finally gotten things ironed out. I will go over it and submit an application per our most recent approved frac sundry(L-200a). From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, June 14, 2017 10:59 AM To: Wages, David Cc: Carlisle, Samantha J (DOA) Subject: RE: PBU S-109 (PTD #202-245, Sundry #316-444) -Application to Fracture Stimulate - Request for Additional Information 1 Loepp, Victoria T (DOA) From: Wages, David <David.Wages@bp.com> Sent: Thursday, December 21, 2017 3:44 PM To: Loepp, Victoria T (DOA) Cc: Wallace, Chris D (DOA); Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: RE: PBU P1-20 (PTD 192-094; Sundry 317-548) Mechanical Integrity Well Data Follow Up Flag: Follow up Flag Status: Flagged P1-07a: Original packer at 9808'workover has the upper completion packer at 9637' G4" 7/18/19 TIFL passed 7/29/2010 Combo MIT to 1000 psi passed j) P1-12: Packer at 9605' ,° 2/16/2014 AOGCC MITIA to 2600 psi passed r 0 �J" 3/8/2010 AOGCC MITIA passed to 2300 psi V �. AV P1-17: ,6 Original packer at 9433' However,a.workover has the new upper completion packer at 5901' 1` a7 10/21/2014 TIFL passed 9/27/2014 TIFL passed (� \470 8/15/2007 MIT-OA passed to 1000 psi \ l P1-18a: Packer @ 9741' MD 6/15/2017 CMITTxIA passed to 2800 psi 4/13/2017 MIT-IA passed to 2500 psi P1-18: The parent well to P1-18a,was plugged and abandoned 5/2002.The top of the whipstock is at 4610'. I do appreciate your guy's patience in all this, I am presently updating our template to include all these updates. David Wages BP AK I Completion Engineer 900 E.Benson Blvd 1744c I Anchorage,AK 99515 Direct: +1.907.564.5669 I Mobile: +1.713.380.9836 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, December 20, 2017 9:22 AM To: Wages, David Cc: Wallace, Chris D (DOA); Schwartz, Guy L (DOA); Davies, Stephen F(DOA) Subject: RE: PBU P1-20 (PTD 192-094; Sundry 317-548) Mechanical Integrity Well Data David, Thanx for the information provided. For the five wells in the Fracturing Area of Review, please add to your table mechanical integrity information which may include MIT-lAs, production casing pressure testing including the date and 1 the test pressure. Also, please include packer depth.The five wells identified are P1-07a, P1-12, P1-17, P1-18 and P1- 18a.This information satisfies 20 AAC 25.283(a)(10). Thanx in advance, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppl alaska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Davies,Stephen F(DOA) Sent:Tuesday, December 19, 2017 8:59 AM To:Wages, David <David.Wages@bp.com> Cc:Wallace,Chris D(DOA)<chris.wallace(a1alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>;Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Subject: RE: PBU P1-20(PTD 192-094; Sundry 317-548) Thank you, David. We'll work through the additional information that you sent, below. In the meantime, at least one section of my December 7th email,containing many questions and requests, still needs to be addressed. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of,orientation of,and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. The map accompanying BP's application displays only the Terrace Fault, a down-to-the- north normal fault that trends east-southeast. No geological description or discussion is provided. A more detailed discussion is needed, and it should address the following topics: Does this fault stop within the upper confining layer,or does it continue upward into shallower strata? Do any of the wells within the Wellbore Confining and Fracturing Area of Review intersect the fault? If so,at what depths (both MD and TVDSS)?While drilling through the fault, did any of the wells encounter abnormal pressure or loose circulation? If so,which ones? Please briefly describe each incident. Do reservoir pressure data or production/injection data indicate this fault is sealing or porous? Please explain. Based on available information, could the fault serve as a conduit for upward escape of the fracturing fluids? If so, into which overlying strata? What monitoring/mitigations measures are planned? 2 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, December 20, 2017 3:05 PM To: 'Wages, David' Cc: Wallace, Chris D (DOA); Schwartz, Guy L(DOA); Loepp, Victoria T (DOA) Subject: RE: PBU P1-20 (PTD 192-094; Sundry 317-548) Mechanical Integrity Well Data David, The AOGCC's hydraulic fracturing regulations can be found online at http://www.legis.state.ak.us/basis/aac.asp#20.25.283. Specific references are cited in red-colored text, below. It sounds like you guys are looking for two maps. 1) To include the %2 mile cylinder along the entire wellbore which identifies every well within that area. Each of those wells on the table that we have provided for the past few years. See 20 AAC 25.283(1), 20 AAC 25.283(2), 20 AAC 25.283(3), 20 AAC 25.283(4), 20 AAC 25.283(10), and 20 AAC 25.283(11). 2) Another map of a %2 mile cylinder along the fracturing interval with increased scrutiny on those wells per below. See 20 AAC 25.283(1), 20 AAC 25.283(2), 20 AAC 25.283(3), 20 AAC 25.283(4), 20 AAC 25.283(10),and 20 AAC 25.283(11). FYI Steve, our geologists are on vacation so we probably won't get further information of the terrance fault per your request until after the holidays. Sorry to hear that the geologists are out. Doesn't BP have additional geologists who can fill in when needed? Just curious why the additional scrutiny? BP is not being singled-out; we simply seek BP's adequate compliance with 20 AAC 25.283(11). Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Wages, David[mailto:David.Wages@bp.com] Sent:Wednesday, December 20, 2017 11:25 AM To: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Cc:Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU P1-20(PTD 192-094; Sundry 317-548) Mechanical Integrity Well Data It sounds like you guys are looking for two maps. 1) To include the 1/2 mile cylinder along the entire wellbore which identifies every well within that area. Each of those wells on the table that we have provided for the past few years. 1 2) Another map of a Y2 mile cylinder along the fracturing interval with increased scrutiny on those wells per below. Is the above correct? FYI Steve, our geologists are on vacation so we probably won't get further information of the terrance fault per your request until after the holidays.Just curious why the additional scrutiny? No matter what the fault is juxtaposed to, we will stop pumping operations if connection to the fault is seen. Below the kalubik in this well is the Kuparuk,where all of PM1 wells are producing from. Above it, the HRZ. We'd have to grow over 200' upwards to get above the HRZ. Our modelling software, with inputs from sonic logs to determine local stresses, indicate that the frac is more likely to grow downward rather than up. In fact, we intend to limit downward growth by limiting the sand/fluid volumes to be pumped so as to avoid downward growth/connection to the wet Kuparuk. David Wages BPI AK I Completion Engineer 900 E. Benson Blvd I /44c I Anchorage,AK 99515 Direct: +1.907.5645669 I Mobile: +1.713.380.9836 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent: Wednesday, December 20, 2017 9:22 AM To: Wages, David - Cc: Wallace, Chris D (DOA); Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: RE: PBU P1-20 (PTD 192-094; Sundry 317-548) Mechanical Integrity Well Data David, Thanx for the information provided. For the five wells in the Fracturing Area of Review, please add to your table mechanical integrity information which may include MIT-lAs, production casing pressure testing including the date and the test pressure. Also, please include packer depth.The five wells identified are P1-07a, P1-12, P1-17, P1-18 and P1- 18a.This information satisfies 20 AAC 25.283(a)(10). Thanx in advance, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeopt alaska.clov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Vit ria Loepp at(907)793-1247 or Victorialoem@alaska.gov From: Davies,Stephen F(DOA) Sent:Tuesday, December 19, 2017 8:59 AM To:Wages, David <David.Wages@bp.com> Cc:Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov>;Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Subject: RE: PBU P1-20(PTD 192-094; Sundry 317-548) 2 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, December 20, 2017 9:22 AM To: Wages, David Cc: Wallace, Chris D(DOA); Schwartz, Guy L(DOA); Davies, Stephen F (DOA) Subject: RE: PBU P1-20 (PTD 192-094;Sundry 317-548) Mechanical Integrity Well Data David, Thanx for the information provided. For the five wells in the Fracturing Area of Review, please add to your table mechanical integrity information which may include MIT-lAs, production casing pressure testing including the date and the test pressure. Also, please include packer depth.The five wells identified are P1-07a, P1-12, P1-17, P1-18 and P1- 18a.This information satisfies 20 AAC 25.283(a)(10). Thanx in advance, Victoria Victoria Loepp Senior Petroleum Engineer • State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa)alaska.nov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Davies,Stephen F(DOA) Sent:Tuesday, December 19,2017 8:59 AM To:Wages,David<David.Wages@bp.com> Cc:Wallace,Chris D(DOA)<chris.wallace@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>;Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Subject: RE: PBU P1-20(PTD 192-094;Sundry 317-548) Thank you, David. We'll work through the additional information that you sent, below. In the meantime,at least one section of my December 7th email,containing many questions and requests, still needs to be addressed. Regulation Deficient Information 20 MC 25.283(a)(11) 20 MC 25.283(a)(11)—provide the location of,orientation of,and geological data for each known or suspected fault or fracture that may transect the confining zones,and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. 1 r j 1 1 1 a. 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Well Status Well Type P1-01 Operable Water Injector P1-02 Abandoned P1-02A Operable Producer P1-03 Operable Producer P1-04 Operable Producer P1-05 Operable Producer P1-06 Operable Producer P1-07 Abandoned P1-07A Operable Producer P1-08 Abandoned P1-08A Operable Producer P1-08P81 Abandoned P1-09 Operable Producer P1-11 Operable Producer P1-12 Operable Water Injector P1-122 Operable MI Injector P1-13 Operable Producer P1-14 Operable Water Injector P1-16 Operable MI Injector P1.17 Operable Producer P1-18 Abandoned P1-18A Operable Producer P1-20 Operable Producer P1-21 Operable Water Injector P1-23 Operable Producer P1-24 Operable Producer P1-24L1 Operable Producer P1-24L1-01 Operable Producer P1-25 Operable Water Injector P1-G1 Operable Gas Injector Below is the cement top evaluation: 2 Welt Name Casing Type Casing Size Casing Depth Hole Size Vol cmc TOC est,via TOC TOC ,Top of pay interval Zonal Isolation? Inches Feet Inches Cu Ft MDFeet TVossleet TVOssFeet P1.01 pc Production Casing 9.625 13295 12.25 1437.5 VVolumetric 9761 6386 6804 Yes P1-01 pi Production Liner 7 1124 8 5 345.25 volumetric 11785 513 8804 Yes Fully cemented l P1.02a pi Production Liner 4.5 11403 6 230 Volumetric 9341 7611 8573 Yes P1-03 pc Production Casing 9.62.5 11413 12.25 7245 Volumetric 9632 6797 8738 YeS P1.03 p 'Production Liner , 7 12744 8 5 345 Volumetric 11089 7892 8738 Yes Cement Volume' P1.04 pc Production Casing 7.625 11637_ 9.875 710 Volumetric 9091 7178 8629 Yes P1-05 Pc Production Casing 7.625 13825 9.875 801 Volumetric 10953 7502 8678 Yes P1-06 pc Production easing 7 6023 8 5 1349 Volumetric 0 0 8607 Yes P1-06 pi Production Liner 4,5 12139 6 408.25 Volumetric N/A N/A 6607 N/A P1.07 PC Production Casing 9.625 9471 12 25 1638 8 Volumetric 5442 4964 8622 Yes y1.07 p Production Liner 7 11098 8 5 546.25 Volumetric 7781 6708 8622 Yes P1-08a pc ProdurnonCasing 7.625 10193 9.875 756 Volumetric 7.482 6946 8480 Yes P2.08a pi Product,on Casing 4 5 10900 6 75 0 N/A N/A N/A 8480 N/A Cemented in pla P1.09 pc ,ProductionCasing 7 11165 8.5 316.25 Volumetric 9245 7763 8605 Yes P1.09 pi Production Liner 4.5 14475 6 469.2 Volumetric 10269 8436 8605 Yes P1.11 pc Production Casing 9.675 12272 12.25 440,Volumetric 11190 8024 8725 Yes P1.11 p Production liner 7 12950 85 259 Volumetric 11377 8147 8725 Yes Fully cemented I P1.12 pc Production Casing 9625 9854 12 25 1121 3 volumetric 7097 67.09 8753 Yes P1.12 p Production Liner 7.625 10749 8.5 773.95 Volumetric 3005 2752 6753 Yes Cement to Liner I P1-122 pc Production Casing 9.675 10687 12.25 O Log 5510 3300 8023_Yes Verified via Log P1-121 pi Production Liner 7 36324 8.5 0 Log 13630 6630 8023 Yes Verified via Log P1.13 pc Production Casing. 7.625 10275 9.875 897 Volumetric 7059 6730 9112 Yes P1-13 p Production Liner 4 5� 11010 6 75 0 N/A N/A N/A 9112 N/A P1.14 pc _Production Casing 7.625 11761 9.875 493 Volumetric 9993 7875 8676 Yes P1-16 pc Production Casing 7.625 14546 9.875 522,Volumetric 12674 8115 8833 Yes P1-17 pc Production Casing 7 625 10518 9 875 633 Volumetric 8246 6986 8598 yes P1.18 pc Production Casing 7 11264 8.75 266.8 Volumetric 9897 8738 8573 Yes Weil has been P. P1-18e pc Production Casing 7 10623 8.75 454.25 Volumetric 8296 7331 6468 Yes P1-20 pc Production Casing, 9.625 9637 72 25 1144 Volumetric 6824 6394 6680 Yes P1.20 pi Production Liner 7 10500: 8.5 211 Volumetric 9219 8303 8680 Yes Cement to liner I P1-21 pc Production Casing 7,625 11513 9.875 667 Volumetric 9122 7306 8751 Yes. P1.20 pi Production Liner 7 10500 9.5 211 Volumetric 9219 8303 8680 Yes Cement to liner I P1-21 pc Production Casing 7.625 11513 9.875 667 Volumetric 9122 7306 6751 Yes P3.23 pc Production Casing' 7 13423 3 5 310.5 volumetric 11533 8003 8859 Yes P1.24 pc Production Casing 7 12470 8.5 442.75 Volumetric 9782 6852 8725 Yes P1-24 pl Production Liner 2.875`14754 3.25 0 No cement N/A N/A 8725 N/A to zone sidetraci P1.25 pc Production Casing 9.625 13817 12.25 7I4 5 Volumetric 12036 , 6875 8892 Yes P1-25 p Production Liner 7 14797 8.5 920 Volumetric 9211 5510 8892 Yes PI-G1 PC Production Casing 9.625 8607 12 25 500 Volumetric 7378 7293 8467 Yes P1-G1 p1 Production Liner 7 8840 8.5 115 Volumetric 2142 7983 8467 Yes Cement to top of P2-55 pc Production Casing, 9.625_ 14787. 12.25_ 4952 Volumetric_ :632_ 2539_ 8892LYes Plug bumped am I believe the cement top evaluation to be over the top as far as how it compares to what Conoco sent you. If you like, we could have a quick conversation to discuss exactly what we need to submit one last time. I think we are both in agreement, but I want to make sure so as to prevent further delays. David Wages BP I AK I Completion Engineer '900 E. Benson Blvd 144c I Anchorage,AK 99515 Direct: +]..907.564.5669 I Mobile: -1.713.380.9836 From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Thursday, December 07, 2017 9:32 AM To: Wages, David Cc: Wallace, Chris D (DOA); Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Subject: FW: PBU P1-20 (PTD 192-094; Sundry 317-548) David, After discussing with AOGCC's senior staff, we all must adhere to a strict reading of the fracturing regulations. Please provide the following information to support BP's application to hydraulically fracture well PBU PTM P1-20: 3 Well Status Well Type P1-01 Operable Water Injector P1-02 Abandoned P1-02A Operable Producer P1-03 Operable Producer P1-04 Operable Producer P1-05 Operable Producer P1-06 Operable Producer P1-07 Abandoned P1-07A Operable Producer ✓ P1-08 Abandoned P1-08A Operable Producer P1-08PB1 Abandoned P1-09 Operable Producer P1-11 Operable Producer P1-12 Operable Water Injector ✓ P1-122 Operable Ml Injector P1-13 Operable Producer P1-14 Operable Water Injector P1-16 Operable MI Injector P1-17 Operable Producer P1-18 Abandoned ✓ P1-18A Operable Producer P1-20 Operable Producer P1-21 Operable Water Injector P1-23 Operable Producer P1-24 Operable Producer P1-24L1 Operable Producer P1-24L1-01 Operable Producer P1-25 Operable Water Injector P1-G1 Operable Gas Injector Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i) and (ii) states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (2) a plat(C) identifying for all well types (i) each well penetration, if any, within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration." The intent of this regulation is to identify all wells within a buffer zone of one-half mile radius that surrounds the entire P1-20 wellbore trajectory(let's informally call this the "Wellbore Trajectory Area of Review") that are potential conduits for upward migration of fracturing fluids. Examples here are wells Pt Mc 02, P1-07, P1-12, P1-18, P1-21, P1-23, and others,that have lengthy sections of uncemented annular space open between casing shoes and the top of cement for subsequent casing strings. Accordingly,the Wellbore Trajectory Area of Review for PBU P1-20 intended by regulation encompasses all of the PBU P1-20 wellbore trajectory—from TD to ground surface—and not just the portion of the well that is open to the Kalubik formation as shown on the plat that accompanies BP's application. Page 1 of the attached file is an example from that shows the Wellbore Trajectory Area of Review provided by another operator that is in the public record. The entire application by that operator is available for review through AOGCC's online WebLink application at http://aogweb.state.ak.us/WebLink/Browse.aspx?dbid=0. The Permit to Drill number for this particular example is 216-039, and the application is shown on pages 73 through 106 of Well History file 216-039. If you have difficulty navigating to this file, call and I will help you. Please provide a revised plat that identifies each well within the Wellbore Trajectory Area of Review for P1-20 and the source of information used to identify each well penetration. Regulation Deficient Information 20 AAC 25.283(a)(10) Regulation 20 AAC 25.283(a)(10) requires: "the location, the orientation, and a report on the mechanical condition of each well that may transect the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory;" The intent of this regulation is to identify all wells that penetrate the confining layers above and beneath the fracturing layer within a buffer zone of one-half mile radius that surrounds the portion of P1-20 that penetrates the upper confining layer,the fracturing layer, and the lower confining layer(let's informally call this the "Wellbore Confining and Fracturing Area of Review").These well-penetrations are potential points of fracture-fluid escape from the fracturing layer. In this instance,those potential escape-points are every well that penetrates the Hue and HRZ shales (the upper confining layer),the Kalubik (fracturing layer) and the Kuparuk and Miluveach (the lower confining layer) within a one- half mile radius of the points where PBU P1-20 cuts through the upper confining layer and reaches TD in the lower confining layer. Page 1 of the attached file is an example from that shows the Wellbore Confining and Fracturing Area of Review provided by another operator, although they call this the "1/2 Mi. Frac Point Radius." BP's application currently lists four production wells within the Wellbore Confining and Fracturing Area of Review(P1-07a, P1-12, P1-18 and P1-18a).The map in my workstation 4 indicates at least five wells penetrate the confining and fracturing intervals within this area, the four wells listed above plus P1-17. In the Sundry Application to fracture P1-20, BP presents only estimated top-of-cement information for three wells(P1-07A, P1-12, and P1-18A). The report on mechanical condition must include integrity testing information along with cementing information for each of these nearby wells(Were the casing strings pressure-tested?When?To what psi? Did the well pass an MIT? If so, when?Cement volume pumped? Brief job summary? Plug bumped? Did losses occur?Cement tagged?Cement evaluation log run? Estimated tops (both MD,TVDSS)? How was each top determined?). Please provide the location, the orientation, and a mechanical-condition report for every well that transects the confining layers within the Wellbore Confining and Fracturing Area of Review. Pages 3 to 5 of the attached file is an example of mechanical integrity information provided by another operator. Their spreadsheet format is ideal for clear presentation of both cement and mechanical integrity information, and it allows quick review. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. The map accompanying BP's application displays only the Terrace Fault, a down-to-the- north normal fault that trends east-southeast. No geological description or discussion is provided. A more detailed discussion is needed,and it should address the following topics: Does this fault stop within the upper confining layer, or does it continue upward into shallower strata? Do any of the wells within the Wellbore Confining and Fracturing Area of Review intersect the fault? If so, at what depths (both MD and TVDSS)?While drilling through the fault, did any of the wells encounter abnormal pressure or loose circulation? If so, which ones? Please briefly describe each incident. Do reservoir pressure data or production/injection data indicate this fault is sealing or porous? Please explain. Based on available information, could the fault serve as a conduit for upward escape of the fracturing fluids? If so, into which overlying strata? What monitoring/mitigations measures are planned? Pages 6 to 8 of the attached file is an example of the fault and fracture information provided by another operator. The discussions are clear, concise and, along with the tables provided, and they allow quick review of the required information. Also, the map accompanying BP's application displays only the Terrace Fault, a down-to- the-north normal fault that trends east-northeast. That same map shows a different predicted directional trend for the induced fracture (about 30 degrees east of south). What is the basis for BP's belief that the induced fracture(s)will trend southeast rather than east-northeast? For clarity of the public record from the point of view of future users, each Sundry Application to conduct hydraulic fracturing operations should be complete as a stand-alone document. In other words, all required information should be presented clearly within each application. 5 Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message,including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent:Thursday, November 30, 2017 4:45 PM To: Davies, Stephen F(DOA) <steve.davies@alaska.gov> Subject: RE: PBU P1-20(PTD 192-094; Sundry 317-548) Steve, If you wouldn't mind giving me a call at your convenience, I would appreciate it. Have questions regarding your note below and past approved sundries (L-200a and P1-23 for example). David Wages BP I AK I Completion Lngineer 900 E.Benson Blvd 1744c I Anchorage,AK 99515 Direct: +1.907.564.5669 I Mobile: +1.713.380.9836 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, November 29, 2017 6:19 PM To: Wages, David Subject: PBU P1-20 (PTD 192-094; Sundry 317-548) David, I forwarded to AOGCC's senior staff your requested priority order for the four BP Sundry Applications for fracturing operations. For PBU P1-20,the highest priority application, please provide the following information: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i) and (ii) states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520,the application must include (2) a plat (C) identifying for all well types (i) each well penetration, if any, within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration. Accordingly,the Area of Review(AOR) for PBU P1-20 encompasses all of PBU P1-20-from TD to ground surface—and not just the portion of the well that is open to the Kalubik and Kuparuk formations as shown on BP's plat that accompanies the application. Please provide a revised plat that displays the AOR as encompassing all lands within 1/2 mile of the entire trajectory of PBU P1-20 and provide the required information listed above. Regulation Deficient Information 20 AAC 25.283(a)(10) BP's application currently lists only four wells within the AOR. Please provide the location, the orientation, and a report on the mechanical condition of each well that may transect 6 the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. I will let you know if I need additional information for my portion of the application review. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 7 Well Status Well Type P1-01 Operable Water Injector P1-02 Abandoned P1-02A Operable Producer P1-03 Operable Producer P1-04 Operable Producer P1-05 Operable Producer P1-06 Operable Producer P1-07 Abandoned P1-07A Operable Producer P1-08 Abandoned P1-08A Operable Producer P1-08PB1 Abandoned P1-09 Operable Producer P1-11 Operable Producer P1-12 Operable Water Injector P1-122 Operable MI Injector P1-13 Operable Producer P1-14 Operable Water Injector P1-16 Operable MI Injector P1-17 Operable Producer P1-18 Abandoned P1-18A Operable Producer P1-20 Operable Producer P1-21 Operable Water Injector P1-23 Operable Producer P1-24 Operable Producer P1-24L1 Operable Producer P1-24L1-01 Operable Producer P1-25 Operable Water Injector P1-G1 Operable Gas Injector Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, December 7, 2017 9:32 AM To: david.wages@bp.com Cc: Wallace, Chris D (DOA); Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Subject: FW: PBU P1-20 (PTD 192-094; Sundry 317-548) Attachments: Fracturing_Application_Example 216-039_Selected_Pages.pdf David, After discussing with AOGCC's senior staff,we all must adhere to a strict reading of the fracturing regulations. Please provide the following information to support BP's application to hydraulically fracture well PBU PTM P1-20: Regulation Deficient Information 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i) and (ii) states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520,the application must include (2) a plat (C) identifying for all well types (i) each well penetration, if any,within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration." The intent of this regulation is to identify all wells within a buffer zone of one-half mile radius that surrounds the entire P1-20 wellbore trajectory(let's informally call this the "Wellbore Trajectory Area of Review")that are potential conduits for upward migration of fracturing fluids. Examples here are wells Pt Mc 02, P1-07, P1-12, P1-18, P1-21, P1-23,and others,that have lengthy sections of uncemented annular space open between casing shoes and the top of cement for subsequent casing strings. Accordingly,the Wellbore Trajectory Area of Review for PBU P1-20 intended by regulation encompasses all of the PBU P1-20 wellbore trajectory—from TD to ground surface—and not just the portion of the well that is open to the Kalubik formation as shown on the plat that accompanies BP's application. Page 1 of the attached file is an example from that shows the Wellbore Trajectory Area of Review provided by another operator that is in the public record. The entire application by that operator is available for review through AOGCC's online WebLink application at http://aogweb.state.ak.us/WebLink/Browse.aspx?dbid=0. The Permit to Drill number for this particular example is 216-039, and the application is shown on pages 73 through 106 of Well History file 216-039. If you have difficulty navigating to this file, call and I will help you. Please provide a revised plat that identifies each well within the Wellbore Trajectory Area of Review for P1-20 and the source of information used to identify each well penetration. Regulation Deficient Information 20 AAC 25.283(a)(10) Regulation 20 AAC 25.283(a)(10) requires: "the location,the orientation, and a report on the mechanical condition of each well that may transect the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory;" The intent of this regulation is to identify all wells that penetrate the confining layers above and beneath the fracturing layer within a buffer zone of one-half mile radius that surrounds the portion of P1-20 that penetrates the upper confining layer, the fracturing layer, and the lower confining layer(let's informally call this the "Wellbore Confining and Fracturing Area of Review").These well-penetrations are potential points of fracture-fluid escape from the fracturing layer. In this instance, those potential escape-points are every well that penetrates the Hue and HRZ shales(the upper confining layer),the Kalubik (fracturing layer) and the Kuparuk and Miluveach (the lower confining layer)within a one- half mile radius of the points where PBU P1-20 cuts through the upper confining layer and reaches TD in the lower confining layer. Page 1 of the attached file is an example from that shows the Wellbore Confining and Fracturing Area of Review provided by another operator, although they call this the "1/2 Mi. Frac Point Radius." BP's application currently lists four production wells within the Wellbore Confining and Fracturing Area of Review(P1-07a, P1-12, P1-18 and P1-18a).The map in my workstation indicates at least five wells penetrate the confining and fracturing intervals within this area, the four wells listed above plus P1-17. In the Sundry Application to fracture P1-20, BP presents only estimated top-of-cement information for three wells (P1-07A, P1-12, and P1-18A). The report on mechanical condition must include integrity testing information along with cementing information for each of these nearby wells (Were the casing strings pressure-tested?When?To what psi? Did the well pass an MIT? If so, when?Cement volume pumped? Brief job summary? Plug bumped? Did losses occur?Cement tagged?Cement evaluation log run? Estimated tops (both MD,TVDSS)? How was each top determined?). Please provide the location,the orientation, and a mechanical-condition report for every well that transects the confining layers within the Wellbore Confining and Fracturing Area of Review. Pages 3 to 5 of the attached file is an example of mechanical integrity information provided by another operator. Their spreadsheet format is ideal for clear presentation of both cement and mechanical integrity information, and it allows quick review. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of, orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. The map accompanying BP's application displays only the Terrace Fault, a down-to-the- north normal fault that trends east-southeast. No geological description or discussion is provided. A more detailed discussion is needed, and it should address the following topics: Does this fault stop within the upper confining layer, or does it continue upward into shallower strata? Do any of the wells within the Wellbore Confining and Fracturing Area of Review intersect the fault? If so, at what depths (both MD and TVDSS)?While drilling through the fault, did any of the wells encounter abnormal pressure or loose circulation? If so, which ones? Please briefly describe each incident. Do reservoir pressure data or production/injection data indicate this fault is sealing or porous? Please explain. Based on available information, could the fault serve as a conduit for upward escape of the fracturing fluids? If so, into which overlying strata? What monitoring/mitigations measures are planned? 2 Pages 6 to 8 of the attached file is an example of the fault and fracture information provided by another operator. The discussions are clear, concise and,along with the tables provided,and they allow quick review of the required information. Also, the map accompanying BP's application displays only the Terrace Fault,a down-to- the-north normal fault that trends east-northeast. That same map shows a different predicted directional trend for the induced fracture (about 30 degrees east of south). What is the basis for BP's belief that the induced fracture(s)will trend southeast rather than east-northeast? For clarity of the public record from the point of view of future users, each Sundry Application to conduct hydraulic fracturing operations should be complete as a stand-alone document. In other words,all required information should be presented clearly within each application. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent:Thursday, November 30, 2017 4:45 PM To: Davies, Stephen F(DOA) <steve.davies@alaska.gov> Subject: RE: PBU P1-20(PTD 192-094;Sundry 317-548) Steve, If you wouldn't mind giving me a call at your convenience, I would appreciate it. Have questions regarding your note below and past approved sundries(L-200a and P1-23 for example). David Wages BP I AK I Completion Engineer 900 E.Benson Blvd I 744c I Anchorage,AK 99515 Direct: +1.907.564.5669 I Mobile: +1.713.380.9836 From: Davies, Stephen F (DOA) [mailto:steve.davies@>alaska.gov] Sent: Wednesday, November 29, 2017 6:19 PM To: Wages, David Subject: PBU P1-20 (PTD 192-094; Sundry 317-548) David, I forwarded to AOGCC's senior staff your requested priority order for the four BP Sundry Applications for fracturing operations. For PBU P1-20,the highest priority application, please provide the following information: Regulation Deficient Information 3 20 AAC 25.283(a)(2)(C) Regulation 20 AAC 25.283(a)(2)(C)(i) and (ii) states in part: (a)"...Unless modified or altered by pool rules established under 20 AAC 25.520,the application must include (2)a plat (C) identifying for all well types (i) each well penetration, if any, within one-half mile of the current or proposed wellbore trajectory and fracturing interval and...(ii)the source of information used in identifying each well penetration. Accordingly,the Area of Review(AOR)for PBU P1-20 encompasses all of PBU P1-20—from TD to ground surface—and not just the portion of the well that is open to the Kalubik and Kuparuk formations as shown on BP's plat that accompanies the application. Please provide a revised plat that displays the AOR as encompassing all lands within%z mile of the entire trajectory of PBU P1-20 and provide the required information listed above. Regulation Deficient Information 20 AAC 25.283(a)(10) BP's application currently lists only four wells within the AOR. Please provide the location, the orientation, and a report on the mechanical condition of each well that may transect the confining zones, and information sufficient to support a determination that the well will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Regulation Deficient Information 20 AAC 25.283(a)(11) 20 AAC 25.283(a)(11)—provide the location of,orientation of, and geological data for each known or suspected fault or fracture that may transect the confining zones, and information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one- half mile radius of the proposed wellbore trajectory. I will let you know if I need additional information for my portion of the application review. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 4 • • Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-05 Landowners i ConocoPhillips Alaska,lrc. 2S-05 N Lease Plat • 6 0 01.1. Ci 045 0€ t.l les ALIULJYRS ADL.02�.�590 74� AAz558 9 7 2S-13L1 2S-11 r b 9 7 tG 1 j.' /2:734 2S-07 /// 2K-1 1 L 2S-02ii 15 ..P13) 2S-13P61 \ t\ Al ,,,,,,....,- ire V, ilift ADL025603 itilf.RU ADL 125605 "21-'10-8 / . 2S-05All/ J/ 2S-03PB1 2S-01 Kuparuk River trait 2S/-06I 2.S10 / i • Frac Points —25-05 Open Interval 2S-03 r� At;392952 —2S-05 Trajectory -- Q 1/2 Mi.Frac point Radius ADLO2 7 1 0112 Mi.Trajectory Radius 1 —Well Within Trajectory Radius 'e�Unit Tract Number ; --Kuparuk PA .------- - i �CPAI Lease -�-� �.__�� i „'___ • • Table 1: Wells within .5 miles WELL NAME STATUS WELL TYPE 2K-19AL1 ACTIVE PROD 2S-01 ACTIVE PROD 2S-02 ACTIVE PROD 2S-03 ACTIVE PROD 2S-03PB1 PA EXPEND 2S-04 ACTIVE PROD 2S-04PB1 PA EXPEND 2S-07 ACTIVE PROD 2S-08 ACTIVE PROD 2S-10 ACTIVE PROD 2S-11 ACTIVE PROD 2S-13 PROP SVC 2S-13L1 PROP SVC 2S-13PB1 PA EXPEND KRU 21-10-8 PA PROD • ! SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON • MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2S-03: The 7-5/8" casing cement report on 2/11/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,103 psi and the floats were checked and they held. 2S-07: The 7 & 5/8 casing cement pump report on 8/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.6 ppg mud. The plug bumped at 1,251 psi and the floats were checked and they held. 2S-02: The 7 & 5/8 casing cement pump report on 7/1/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.4 ppg LSND. The plug bumped at 1,505psi and the floats were checked and they held. 2S-10: The 7 & 5/8 casing cement pump report on 9/2/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.5 ppg mud. The plug bumped at 1,450 psi and the floats were checked and they held. 2S-01: The 7-5/8" casing cement report on 1/3/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,100 psi and the floats were checked and they held. KRU 21-10-8: KRU 21-10-8 was plugged and abandoned as per state regulations on 4/28/1989. 2S05 Fracture Stimulation Area of Review Top of A-sand OB Top of A-Sand Top of Cement Top of Cement Tap of Cement Cement Operations WELL NAME STATUS Casing axe Pool(MD) OR Pool ITVDfiSi (MD) (iVDSS) Determined BY Rearm*Status Zonal Wilda' Summary Mechanical Integrity Stage 1:730 sx 15.8 ppg Clan Frsleeves open for IOC a 5,800'MD&Planned G G 75/8"rasing ac 25-05 PROD 7-5/8" 8,930' 6,164' 5,844 4,494 Calculated production packer 00379'MD est,) Stage 2:256 sx 15.8ppg Cass pressure tested to G 3500 psi on 5/29/16 7- casing Frac sleeves open for TOC a 7.308'&Packer @ sure tested to 25.03 PROD 7-5/8" 9,150' 6,173' 7,306' 5,566' Calculated production 8,652'MD 654M IS.Sppg GassG pressure 3500 psi on 2/15/16 25-02 191 7&5/8" 12.271' 6,336'TVDI 8,812' 4,624' Sonic Log Slotted liner open TOC 8.812'&Packer 80 12,431' 501 sus 15.8ppg lass 6 Passing MIT/267IA MD 3 Pas psi pn 7to 35 25-07 191 7&5/8' 8,004' 6,311'TVD 4,900' 4.185' Sonic Log Slotted liner open TOC 4,900'&Packer a 7,720' 377 sa GasBLOK,155 ax Passing MEM to MO GasBLDK 3000 psi on 9/5/15 • • 25-10 ISO 7&5/8" 8,102' 6,264' 5,335' 4,800' Sonic Log Slotted liner open CBL TOC 5,335'&Packer @ 365 sx Glass G,130 sx Class G Psing MOIA w 8,085'MD as3500 psi on 9/19/15 25-05 Fracture Stimulation Area of Review Top of A-sand Oil Top of A-Sand Top of Cement Top of Cement Top of Cement [emeM Operations WELL NAME STATUS Casing Sim p001(MO) ql Pod(TVO55) (MD) (TVO55) Determined By Reservoir Status Zonal Isolation Summary WELL Integrity Frac sleeves open for TOC @ 7.308'&Packer 7-5/e"casing 25-03 PROD 7-5/8" 9,150' 6,173' 7,308' 5,566' Calculated production 9,652'MD 654 sx 15.8ppg class G pressure tested to 3500 psi on 2/15/16 25-02 I INJ 7&5/8' 12,271' 6,336' Ali TOC 8,812'&Packer @ 12,431' Passing MITIA to (TVD) 8,812' 4,624' Sonic Log Slotted liner open MD S03 sxs iS.ePpg class G 3500 psi on 7/26/15 —} 25-07 NJ 7&5/e" 8,004' 6,311'ND 4,900' 4,185' Sonic Log Sloped lin pen TIC 4,900'&Packer @ 7,720' 377 sx GasBLOK,155 ax Passing MITIA to MD GasBLOK 3000 psi on 9/5/15 I CBL TOC 5,335&Packer @ Passing MIT/A to 2510 INJ 7&5/8" 8,102' 6,264' 5,335' 4,800' Sonic Log Slotted liner open ! 8,085 MD 365 sx Class G,130 sx Class 3500 psi on9/19)15 • • • • • • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are 13 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-05. The north-south trending faults between 2S-05 and 2S-07 terminate in the Cairn interval, which consists of sands, silts, and shales in this area with an estimated fracture pressure of>12 ppg. Three faults intersect the 2S-05 wellbore and terminate within the confining layer(Fault #1, #2, and#3). Faults#4 and#5 terminate at the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of-16ppg. No losses were observed at any of the fault crossings during drilling of the 2S-05 lateral section. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. 2S-05 Faults MD SSTVD Throw Fault#1(A4/A4) 10562 6182 2(DTS) Fault#2(A4/A4) 10570 6182 2(DTS) Fault#3(A4/A4) 10585 6183 4(DTS) Fault#4(A4/A4) 11958 6181 21(DTS) _ Fault#5(A4/A4) 13684 6146 8(DTS) Two mapped faults within the half mile radius intersect the offset 2S-07 wellbore in the Kuparuk A sands. They also intersect the 2S-05 wellbore and correspond to faults#4 and #5. Both faults terminate in the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of-16ppg. No losses were observed at any faults during drilling of the 2S-07 lateral section. The 2S-05 lateral is greater than 1500' from the 2S-07 wellbore. 2S-07 Fault MD SSTVD Throw Fault#1(A4/A4) 11350 6167 29(DTS) Fault#2(A4/A4) 13022 6142 5(DTS) Two mapped faults within the half mile radius intersect the offset 2S-02 wellbore in the Kuparuk A sands. Fault#2 intersects the 2S-05 wellbore and corresponds to Fault#4 in 2S- 05. Both faults terminate in the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of-16ppg. No losses were observed at the fault during the drilling of the 2S-02 lateral section. The 2S-05 lateral is greater than 1500' west of the 2S-02 wellbore. 2S-02 Fault MD SSTVD Throw Fault#1(A4/A4) 16225 6227 27(DTS) Fault#2(A4/A4) 17488 6214 25(DTS) • • The effective fracture length is estimated to be 420'. All of the fractures will be longitudinal, running parallel to the 2S-05 wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. • • Plat 2: Fault Analysis E 1 ConocoPhillips FsAnalysis �'` � c _. CZ 2..4 Vitt /1/491025510 ACi.C:55;1 i Kuparuk River7:: ? Unit Ik r 1 « /- 2a-cz 17j ON RAE } ' i } r8 rr t, A\ — — I A _ ,„ ir -05 ' •a=t¢-e t D_C:52C3 / \ 1 r �� 1 _.11 �� / r _ r. //rt ssa3Ps1 ;` 2SLDI • Frac Ports ▪ Faults'.S'th n Confining Zone 2S-05.Traectory -'--'D ADLO7se07 1r2 Mi.Frac Pant radius ::- 0t;2 011;2 Mi.Tra;iectorj Radius W'ets Within Frac Pont Rad:us 21.3-OS —Kupan►Pa .,.— 0 CPA'i Lease STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISN - REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑,- Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 'lgp of 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 192-094 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22288-00-00 7. Property Designation(Lease Number): ADL 0028297 8. Well Name and Number: PRUDHOE BAY UN PTM P1-20 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: 'RECEIVED Total Depth: measured 10500 feet Plugs measured 9080/9699 feet true vertical 9453 feet Junk measured feet JAN 3 0 2017 Effective Depth: measured 9080 feet Packer measured See Attachment feet true vertical 8192 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"91.5#1440 42-120 42-120 1490 470 Surface 3352 13-3/8"68#L-80 122-3474 122-3474 5020 2260 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1006 7"26#13Cr80 9493-10499 8538-9451 7240 5410 Perforation Depth: Measured depth: See Attachment feet SCAN True vertical depth: See Attachment feet NEO APR 1 9. 2017, Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 37-9691 37-8717 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"Camco TRDP SSV 1993 1993 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 249 88 5970 2039 721 Subsequent to operation: 347 1046 0 1196 619 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil IZI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-576 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 4"„4„,vf Phone +1 907 564 4424 Date 1/30/17 Form 10-404 Revised 5/2015 + 4C7v/ /2 ` D Submit Original Only • Packers and SSV's Attachment PRUDHOE BAY UN PTM P1-20 SW Name Type MD TVD Depscription P1-20 SSSV 1992.88 1992.88 4-1/2"Camco TRDP SSV P1-20 TBG PACKER 9136 8236.51 4-1/2" Baker D Packer P1-20 PACKER 9500.08 8544.39 7" Baker H Packer P1-20 TBG PACKER 9626.51 8657.9 4-1/2" Baker SABL-3 Packer • • 0) a o 0 0 0 0 0 CO CO CO CD � O V . 0• 0) N O- O- - c05) Nr O co 00 N U) CO CO N- CO M CD ti N- 0) CO U) I- N 4 U) CO 4 cr) 00 CO 01 c0 III III co N O 0) CCS) N Cr L ( O C GDovinCDg.; � E N N- Cn C) v 0) Cornrn v0) 0) OCD rn RS 1 1 1 1 1 1 RS rt a = co N N O tCf 0) N- W . H MaM WO O O 02 O co Q1= _ 4 Z J 0 M C 'N � NUU)) (0N . V \ - 0. 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O D O O Q O < ¢ m � L_ v) co a m "TREE= BAC V113LHEAD= CNV • •AFETY NOTES:TUBING HANGER:RNC IV F ACTUATOR= OT1S P 1 .2 Q 22'M D. 4-1/2"CHR TBG&T"CHR LNR KB.FLEV= 50.8' BF.ELEV= KOP= 3977' I 1983' —{4-112"CA MCO TRDP SSSV,D=3.812 Max Angle= 38"©8869' GAS LET MANDRELS Datum MD= 9838' ST M) TVD DEVTYFE VLV LATCH FORT DATE Datum TVD 8800'SS' 1 3538 3537 2 TGFD DOME TG 16 11/11/11 2 5690 5477 36 TGFD SO TG 22 11/11/11 13-3/8°CSG,68#,K-55/L-80,ID=12.347" — 3500' 3 6889 6447 36 TGRD DMY TG 0 01/03/93 4 7542 6971 37 TGF D DMY TG 0 01/03/93 Minimum ID =2.00" 9080' 5 8273 7554 38 TGFD DMY RK 0 11/11/11 4-112" IBP STOP ON X LOCK 6 9040 8160 38 TGPD DMY TG 0 01/03/93 PRODUCTION MANDRELS ST MD ND DEV TYFE VLV LATCH FORT DATE 7 9186 8277 36 TOED DMY TG 0 01/17/93 8 9441 8492 29 TGFD DMY TG 0 01/03/93 9 9474 8521 28 TGF) DMY TGE 0 01/17/93 tc_: 9080' —141/2"SWS NP,D=3.813" 9080' —4-112"NS FLP STOP w IX LOCK (12/27/16),ID=2.00" Z 9130' --19-5/8"X 4-1/2"BAKER D PKR D=4.75" , ' 9161' —14-1/2"SWS NIP,D=3.813" Ii I 9261' —I CARBIDE BLAST RINGS(9261'-9313') TOP OF 7"LNR H 9506' 1 E 9620' J—7"X 4-1/2"BAKER SABL-3 PKR,ID=3.87-J 9-5/8"CSG,47#,NT-80,ID=8.681' —I 9637' 1--4 k 4-1/2"TBG,12.6#,13-CR-NSCT,.0152 bpf,D=3.958" H 9685' 1 , 9651' H4-1/2"SWS NIP,ID=3.813" PERFORATION RY ' , 9672' H4-112"SWN N6?D=3.725" REF LOG:DUGR ON 10/29/92 9685' —I4-1/2"TIJBNG TAIL,WLEG,D=3.95" ANGLE AT TOP FERE:32"@ 9264' 9686' —E.MO TT LOGGED 01/22/93 Note:Refer to Production DB for historical perf data SEE SPF MERVAL Opn/Sqz DATE 19699' ELM j--[3-3/8"BKR BP(12/25/16) 3-3/8" 4 9264-9310 0 01/04/93 2-7/8" 6 9599-9613 0 12/25/16 ' 2-7/8" 6 9616-9620 0 12/25/16 I 2-7/8" 6 9630-9643 0 12/25/16 3-3/8" 6 9735-9775 C 05/23/04 1 3-3/8" 4 9795-9862 C 01/23/93 ' 3-3/8" 4 9877-9975 C 01/22/93 ' 3-3/8" 6 9880-9890 C 05/23/04 3-3/8" 6 9920-9950 C 05/22/04 1 3-3/8" 6 10005- 10025 C 05/22/04 I 3-3/8" 6 10035- 10055 C 05/22/04 ' 3-3/8" 4 10036-10056 C 01/22/93 PBTD 10408' 7"LNR,26#,CR-13-80,.0383 bpf,D=6.276" H 10500' k'•'•••••-4•4'4'4'4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRt1JHOE BAY UNIT 01/06/93 D16 OI GINAL COMPLETION 12/29/16 JUJMD AD1'RZFS/SET IBP(12/25/16) WELL: P1-20 5/22-5/23/04 MIA/KK ADEEFFS 12/29/16 ZV/JMD SET IBP STOP(12/27/16) FERNIT No: 1920940 08/04/04 GRCITLP SURF CSG CORT 11ON AR No: 50-029-22288-00 05/29/06 DFR/DTM CSG CORRECTIONS(11/24/04) SEC 16,T12N,R14E, 1384'FSL&908'FEL 10/28/11 RW/JMD GLM CORRECTIONS(10/12/11) 11/14/11 MSS/PJC GLV 00(11/11/11) BP Exploration(Alaska) • • a H Z et UJ b d Q Q 2 0 II co to aN Q. pm qm m 4 n m ° a) OD 2 Lu N o.5 o!S g in 0o0 a1 a 0. a0 3 O) L 0 0 8 N 0 �ro 32 m v- IQ- - H 11 W 2 11 CC cf)N 2-2 3 . ¢ - QZ a o mm� - .. 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O d 22002 § 2 " Z .....• 2 i § 1- - 0)._m © r. )- § k 2 § oc R . t a � � O � 22 > O 2z � � 0D222 ® o � aow 13• � 2 = • 1 X30 3k .CI C s < § § < c 2T 3 � CL - � E � E k 2 E @ e * o m o 2 \ _r52 _1 � k / e mo2m0 ƒ n 13 _1af. c0. 3d 32U co co ZS _ ¥ CV / CO cn 01 OA Cl SOF 77.i • • y I 1/7,, A THE STATE Alaska Oil and Gas 1:4 ofLASKA Conservation Commission tri= 333 West Seventh Avenue veiGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Kathy Burton Pad Engineer scmitiED MAR 1 5 201 , BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PTM P1-20 Permit to Drill Number: 192-094 Sundry Number: 316-576 Dear Ms. Burton: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this day of November, 2016. RBDMS LL_Nov 2 8 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPRO LS 20 MC 25.280 ' 1. Type of Request: Abandon ❑ Plug Perforations Ea. Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool Elf . Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 192-094 . 3, Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0. 99519-6612 Stratigraphic ❑ Service 0 6. API Number: 50-029-22288-00-00 - 7. If perforating: 2 What Regulation or Conservation Order governs well spacing in this pool?C a3/75 J8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ NoPTM P1-20 • �t' ri� 9. Property Designation(Lease Number): 10. Field/Pools: RECEIVED ADL 0028297 PRUDHOE BAY,PT MCINTYRE OIL 11. PRESENT WELL CONDITION SUMMARY NOV ® 2016 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: I Effective Depth TVD: MPSP(Ps)i Plugs(MD): 10500 • 9453 . 10408 9369 'le..,A: Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"91.5#H-40 42-120 42-120 1490 470 Surface 3352 13-3/8"68#L-80 122-3474 122-3474 5020 2260 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1006 7"26#13Cr80 9493-10499 8538-9451 7240 5410 Perforation Depth MD(ft): I Perforation Depth TVD(ft): I Tubing Size: Tubing Grade: I Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 Packers and SSSV Type: See Attachment 37-9691 Packers and SSSV MD(ft)and ND(ft): See Attachment 4-1/2"Camco TRDP SSSV 1993, 1992.80 12.Attachments: Proposal Summary ❑ Wellbore Schematic Vf 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Ii3 ' Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ® • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 OpShutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Burton,Kaity be deviated from without prior written approval. Email Kaity.Burton@bp.com Printed Name Burton,Kaity Title Pad Engineer Signature c.11 r ^ Phone +1 907 564 5554 Date /(3/31 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity ElBOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 ,6Q ^C-74-e Other: C- +►11311.6 Post Initial Injection MIT Req'd? Yes 0 No 0 / Spacing Exception Required? Yes 0 No IJ Subsequent Form Required: '0-- 40 4 / Approved by:i COMMISSIONER APPROVED B COMMISSIONYTHE n fie/ Date: f ORIGINAL RBDMS NOV262016 # 17/6/ ',Alia “Irt 116 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ALASKA WELL ACIPTY STATEMENT OF REQUIREMENTS (V2.0,D.,LHD,EAZ, BPG 10/12/15) General Information (Well Name: P1-20 Well Type: Gas Lift Producer API Number: 50-029-22288-00 Well Activity Classification: Conventional 4 Activity Description: Addperfs _ Cost Code/AFE: APBPERFS Field/Reservoir: PTMAC 12 Month Avg IOR, bopd: 20 Job Type: Add Perf Estimated Cost, I • $K: $125 AWGRS Job Scope: PERFORATING Other regulatory requirements? Sundry Form 10-403 None Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Kaity Burton Contact numbers: (907) 564-5554 (907)360-6002 Well Intervention Engineer: Troy Tempel Contact numbers: 907-570-1351 907-570-1351 Lead Engineer: Mark Sauve Contact numbers: (907) 564-4660 (907) 748-2865 Date Created: September 22, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Date Oil Rate Inj Rate Gas Injection GOR FTP or Injection (bopd) (bwpd)Water Rate Choke Setting Gas Lift Rate (scf/stbo) (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 8/17/2012 65 6155bwpd,99�i we 88 355 168 3,609 721 Current Status: Operable Shut In Inclination>70°at Depth(ft) NA Recent H2S (date,ppm) 10/18/2004 600 ppmj Maximum Deviation(Angle and Depth) 38° 8,869' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 1 5 Reservoir pressure(date, ° 9,538' MD prig) 9/21/2016 I 3,943 psi Minimum ID and Depth 3.725" 9,672' MD Reservoir Temp,F 182° F Shut-in Wellhead Pressure 2,400 psi Known mech. integrity problems(specifics) None Last downhole operation(date, operation) 9/21/2016 drift, static, SSSV function Most recent TD tag (date,depth, toolstring OD) 9/21/2016 10,190' MD ISL drift to TD with 3.5"cent If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Kit Fit-for-Service? NO If No,Why? Surface Equipment Comments,well history, P1-20 is currently SI due to high WC and iisp planned for blinding(sleeper project.) It is spec blinded and background information, cannot be flowed in it's own flowline so therefore will need to be flowed through the portable test unit etc: down a neighbor well flowline.A caliper run in 02/2016 showed scale deposition increasing with depth in the tubing reducing ID to 3.5"at the TT. As a last ditch effort for this well and to test the Kaluibik formation potenti.plan to perforate through three strings of pipe teen the Kalubik. In doing this, our perfs will penetrate either side of the 7"x4-1/2"packer and leave open to flow the 4-1/2"x9-5/8"annulus which is also open to perfs in the Stump Island Sand Stone which were shot and tested in 1993. The SISS was proven not to flow at the time, but still these new perfs would be comingling production from the two pools and therefore will need a sundry. In order to best understand the Kalubik formation potential we will isolate the Kuparuk interval from flow. On the bottom side of the packer we would connect the Kaparuk formation open to flow so the well will need to be secured in the liner to prevent Kuparuk flow with the Kalubik flow. P1-20 is offset to P1-07 parent wellbore which produced roughly 450mbo from the Kalubik formation in 1993 and there is enough log evidence to suggest the sand exists in P1-20 and is likely oil bearing. Productivity is unknown but this perf job tests the potential. Please contact the SOR author if: • Well Intervention Details 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Specific Intervention or Well Objectives: 1 Islolate the Kuparuk interval from production,perf and flow the Kalubik 2 3 Key risks,critical issues: Mitigation plan: 1 Inability to flow well None-this is last ditch if it does not flow then there are - no further plans. 2 3 Summary Step# Service Line Activity 1 S RIH with flapper checker and ensure SSSV is open. Drift for 3.38" IBP to 9730' MD. Set window for IBP is below TT and above perfs (9690'-9730'MD.) RIH and set IBP in window between 9690-9730'MD. FB PT well prior to addperfs to ensure isolation. Perforate well per perf table attached tying in to tie-in log annotated and attached. Note this is perforating 2 E the Kalubik sandstone which is part of the Kaparuk pool but will open the previous SISS perfs to flow. Therefore requires a sundry. Note this interval also has scale making gamma tie-in near impossible, CCL markers should be used for main tie-in. 3 F Assist eline with IBP set and secure. PT plug to 1500psi. 4 S Set"IBP stop"on 4 1/2"SWS lock at 9080' MD (WSL discretion to set in another nipple if needed). See detailed drawing in attachments. IBP stop is available at the WLB to thread on the bottom of the lock. Rig up to flow P1-20 down neighbor flowline as P1-20 is blinded and unable to flow in it's own flowline. 5 T POP well and attempt to flow new perforations for minimum of 24 hours. Obtain 12 hour test. If well is struggling to flow, contact APE. Use FL shots to determine GL and FL status. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations (may be NA if no change anticipated due to the intervention) BOPD: unknown MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • • 1 PENDING PERFORATING PROCEDURE ADW Well: P1-20 API N:50-029-22288-00 Date: 9/22/2016 Prod Engr Kelly Burton Office Ph: (907)564-5554 H2S Level: Home Ph: 600 ppm Cell/Pager: (907)360-6002 CC or AFE: APBPERFS WBL Entries IOR Type Work Description Addperfs per procedure.Note,this is through tubing,liner,and casing to access the kalubik formation.Depth correlation is critical so please use the log provided for tie-In. Tie-in logs:SLB Memory SBHP,GR,CCL,press,temp 06/10/2008.SLB Production log 12/12/1993. Well Objectives and PerforatingNotes: Note there are two scanned copies showing pert locations.Each has slightly di Brent L markers but both have proper depth control for pert interval and each show the same significant CCL markers. Both logs are on depth with each other so either can be chosen for tie-in depending on strength of CCL indicators downhole. Note a hand-drawn talley is attached to show actual packer location.We are knowingly shooting perfs on either side of the packer,through pups and some collars.Either log attached can be used for tie-in depending on the quality of CCL marker seen when in hole. Scale in the tubing affects the gamma signiture so you are unlikely to be able to tie-in to gamma hence forth the CCL tir-in. Both logs are attached. Attachment: Tie-in log with proposed perfs annotated-see tie-in log section Reference Log Tie In Log Add 0 feet Log: Production log SBHP to the tie-in log to be on Date: 12/12/1993 6/10/2008 depth with the reference log. Company: SLB SLB Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad'Re/lperf 9,630' 9,643' 9,630' 9,643' 13 6 random 60° Kalubik Ad 9,616' 9,620' 9,616' 9,620' . 4 6 random 60° Kalubik Ad 9,599' 9,613' 9,599' 9,1613' 14 6 random 60° Kalubik Ad Requested Gun Size: 2-7/8" Charge: SLB 2-7/8"PURE Powerjet Nova 2906,HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating No Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Drift: 10,190 R MD on 9/21/2016 Est Res.Pres.@ 8,800'TVDss MD Is 3943 psi Perforation Summary Summary Dist Well: P1-_20Town, Date: APItk 50-029-22288-00 Prod Emyr. Anch Prod Engr .._ P .Center PBTD General Comments: Depths Balance Referenced to BHCS Gm Din. Orient SPF Phasing Zone Adperf/Reperf 0/B/U 0/B/U 0/B/U O/B/U ...._...... 0/B/U - O/B/U ....__....._................ 0/B/U O/B/U 0/B/U _ ....__ 0/B/U _ ...._ • • 'RtE. SAFETY NOTES TUBING HANGER €144C IV.41 NH:J.1E4,1 " A, P 1 -20 22' 4-1 2-C144 TB'S& 7-C14R LW 1983' H * P'.L0 L *JD" A'4 e z • k (1).t) 4/4", "o„ AO& H 350,0" Minimum ID =3.725" @ 9672 4-1/2"PARKER SWN NIPPLE T • Der •^E, S•tf-. ". "J 4'" A'''4C "tits AP I 2E ' .ot/te, 908.0" .114-' 'Se"- s'4" I 1------4916i7-1—F7=7777.71 s - I CA- H 9506' :4 .• ••* EAs J-," /*As ' 1 (...S".4 41 H 9s37 116. I i -4 9651' I I 9612' L I1,, ' ,,tr 13-C R-1,4SCT i"-- t H 9685* 9685* H4-'ea J664_ AL Jj-L„. I 9686' tib-s.9L) I I I 104°8' MAY.**• CR-13-4,0 Vvi 10500" Fej .4` "."..0%15,4ed S tEA 4.4 01/06'93 t16 ORIGINAL COMPLEIKN SPA42-',24.114 ',ALA'4K A-)f aSti P," 46' C.14.PPEC'J2,44 A o4"sr. 2"o sS LPH-ktY CV.; • 4 Set 4.t." 4."4 st .48,1' (LM C.,(0,1"ItL 4.4"4".4 ' '1 144" PJC C , "" b4440/46+041 4436 k • • m Q.o 0 0 0 0 €8 (0 (0 — N f" 'ct to p N V 10 N U 0) N o NO M O CO CO N V m (O CO N- CO p CO (0 N- N- O CO O M co CO CA H co N N O 0)) COO N- V' d CO CO 4-I w O ctLn CO CT) -- EN ti to r7 LU CO 0t CO t CO O) 0) 0) v O / 1 1 ; 1 1 Q NN O Lo o N � V NI-V" L Cr) Ct. 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Q ¢ ¢ w a a 070 zlx M ~ O O 0 0 0 0 0 0 _0 _0 J w w 0 6) 6) 0) 0) 6) 6) 6) CA r- r- Z Z Z O J J D ❑ ❑ m ¢ Q Q = 0 0 a a Ora = 2 0 0 0 nw. 12 1Y Z Jp Z CSO 2220w wwww C4 N Qa a � C: C = v Co IC) N- O O O O L° L° Co Ir) o c y COM6) 1- o6) NuOOMOOMO • F- ❑ CV hs rn Co CO CO M O) O O O o o CC U) cow a) 0- 0 0 LL LL LL LL L.L. LL LL. U LL LL LL • F- aaaaaaaaaaa Qct Q Q Q Q Q Q < Q Q Q Q 0 t C) a 0• co v co v v v v v v d' v v ❑ ❑ 0) O 0) O O O O O O O O O ❑ 0 c CA CD 0) 0 0 0 0 0 0 0 0 0 W Z 0 v- N v- N N N NN N N N N Z w Q w a) e h- COMMMCON N N Na ❑W -JNNNNNNN Z ❑ w 0 W LL1 LL W L2 c- L() LO Co Co L() Co IC) Co Co In Q ❑ J j-- J J J D a 0 CY) ❑ D W J J Q CJ w W < < a (nLL W LL N a a' E CD 0 CD CD CD 0 0 0 0 0 0 0 N N N N N N N N N N N N I I I I ' I I I I I I I LL CLU) O LL N LY a r r r . . . . . . . a a a CL a CL O O O a a a ¢ Q co CL 0 J L O a s • • Packers and SSV's Attachment PTM P1-20 SW Name Type MD TVD Depscription P1-20 SSSV 1992.88 1992.88 4-1/2" Camco TRDP SSSV P1-20 TBG PACKER 9136 8236.51 4-1/2" Baker D Packer P1-20 PACKER 9500.08 8544.39 7" Baker H Packer P1-20 TBG PACKER 9626.51 8657.9 4-1/2" Baker SABL-3 Packer . • S LID 0 Produced Gas (Thousand Cubic Feet ("MCF") per Day) or Gas-Oil Ratio (MCF per Barrel) 0 Y O O O I O O O O O O O O O O O O O O 01 00 LA M N .-1 O N 9I.' O P‘1, > Sly l0 0 P� 15ra I' l0 0s4 13 `°i; ° c'r 10 a '� 0 to> cc i ll to a d) 0 O,. 10 CD {I 13 c Cr tn GO'P 0 ! moo. l0 0 GJ 4� ---------------- -------- --- 1 00 ocs ° O o > N c �� w.. a [I ida s z cO oS / 0a _ - (-0 t dL ° oo i - ‘P -0 1O sib 0.0 00,10 Q l ::7/,..::scit.41:°°:,) 0 _mime 'cri ° d Alto> Q G,4 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 P41. o Q1 CO N l0 V .47 M N e-I Rea Jad aa}e/N }o sla.iies Jo Rea iad Ha }o slaaaes 0 1 C7 0 • • Davies, Stephen F (DOA) From: Burton, Kaity <Kaity.Burton@bp.com> Sent: Wednesday, November 16, 2016 11:08 AM To: Davies, Stephen F (DOA) Subject: RE: PTM P1-20 (PTD 192-094; Sundry Application 316-576) - Question Attachments: 2016.09.22 P1-20 kalubik perf table.pdf Hi Steve- please find the requested perforation summary attached for your review. Thanks! Kaity Burton Point McIntyre PE Base Management Alaska Region Sand Management SPOC (W) 907-564-5554 (C) 907-360-6002 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, November 09, 2016 9:47 AM To: Burton, Kaity Subject: PTM P1-20 (PTD 192-094; Sundry Application 316-576) - Question Kaity, I'm reviewing BP's Sundry Application for PTM P1-20. On page 3 in Summary Step#2,the supporting document states: "Perforate well per perf table attached...". The only perf table included with the application lists only perforations from 1993 and 2004, but no proposed perforations. Could BP please provide a list of these proposed perforations? Thank you. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies(cr�alaska.gov. 1 '. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA X Diskettes, No. ~ [] Other, No/Type OVERSIZED Logs 'of various kinds Other COMMENTS: Scanned by: ianna Vincent Nathan Lowell Date: ¢ g ~,~2~ Is/~')/~' [] TO RE-SCAN Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: ~si OPERABLE: P1 -20 (PTD #1920940) Tubing Integrity Restored • Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] q12-51/ Sent: Thursday, September 22, 2011 7:17 PM Z To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GPMA OSM; AK, OPS GPMA Field O &M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Gerik, Bob G Cc: AK, D &C Well Integrity Coordinator; King, Whitney Subject: OPERABLE: P1 -20 (PTD #1920940) Tubing Integrity Restored All, Producer P1 -20 (PTD #1920940) passed a warm TIFL on 09/21/2011. The passing test confirms the presence of two competent barriers in the wellbore. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 �. (, From: AK, D &C Well Integrity Coordinator Sent: Monday, September 05, 2011 2:07 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GPMA OSM; AK, OPS GPMA Field O &M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D &C reline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East ells Opt Engr; Gerik, Bob G Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: UNDER EVALUATION: P1 -20 (PTD #1920940) Sustained Casing IA Pressure Above MOASP All, Producer P1 -20 (PTD #1920940) has confirmed sustained IA casing pressure -bove MOASP. The wellhead pressures were tubing /IA /OA equal to SSV/2500/240 on 5/4/2010. A TIFL failed on 09/04/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. Slickline: Pull and reset new gas lift design 2. DHD: Re -TIFL after changing out gas lift design 3. WIE: Pending re -TIFL result, evaluate dummying gas lift v, ves and performing an MIT -IA A TIO plot and wellbore schematic have been included f. r reference. Please call if you have any questions or concerns Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 9/23/2011 UNDER EVALUATION: P1 -20 (PTD,920940) Sustained Casing IA Pressurobove MOASP Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIIntegrityCoordinator @bp.com] Tcf6i 9161 I� Sent: Monday, September 05, 2011 2:07 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GPMA OSM; AK, OPS GPMA Field O &M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt' Engr; Gerik, Bob G Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: UNDER EVALUATION: P1 -20 (PTD #1920940) Sustained Casing IA Pressure Above MOASP Attachments: P1 -20 (PTD # 1920940) TIO Plot.doc; P1 -20 (PTD # 1920940) wellbore schematic.pdf All, Producer P1 -20 (PTD #1920940) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV/2500/240 on 5/4/2010. A TIFL failed on 09/04/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. Slickline: Pull and reset new gas lift design 2. DHD: Re -TIFL after changing out gas lift design 3. WIE: Pending re -TIFL result, evaluate dummying gas lift valves and performing an MIT -IA A TIO plot and wellbore schematic have been included for reference. - «P1-20 (PTD # 1920940) TIO Plot.doc» «P1 -20 (PTD # 1920940) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, No41 ` Gerald Murphy (alt. Mehreen Vazir) ??,5 ) > iWo ,; Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 ; .� ,I fd 1 `14 '1 _ 3(0, Pager (907) 659 -5100 Ext. 1154 '' ""�'- P ok- 9/6/2011 PBU P1 -20 PTD # 1920940 9/5/2011 TIO Pressures Plot Well: P1 -20 4,000 - • :;00 - A ti ....,....... -7 --- T bg —R--- IA 2 000 - --A-- OA 00A I —41,- 000A 1 —0n 1..000 - I III y i 1 , r , 06/12.11 07/02/11 07/16/11 07/30/11 08/13/11 03/27/11 TREE = FMC • SAFNIOTES: TUBING HANGER: FMC IV @ WELLHEAD = CIW ACTUATOR = OTIS P1-20 22' MD. 4 CHR TBG & 7" CHR LNR KB. ELEV = 50.8' BF. ELEV =, KOP = 3977' 1983' H 4-1/2" CAMCO TRDP SSSV, ID = 3.812" I Max Angle = 38 @ 8869' I 0 ' GAS LIFT MANDRELS Datum MD = 9838 Datum TVD = 8800 SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3538 3537 2 TGPD TG , 2 5689 5476 36 TGPD TG I 13-3/8" CSG, 68#, K-55/L-80, ID = 12.347" H 3500' H 3 6888 6446 36 TGPD TG 4 7542 6971 37 TGPD TG Minimum ID = 3.725" @ 9672' 5 8272 7554 38 TGPD TG 4-1/2" PARKER SWN NIPPLE , 6 9039 8159 38 TGPD TG PRODUCTION MANDRELS 11111 PERFORATION SUMMARY MD ND DEV TYPE gm LATCH PORT DATE 7 9186 8277 36 TGPD TG REF LOG: DIL/GR ON 10/29/92 8 9440 8492 29 TGPD TG ANGLE AT TOP PERF: 32 @ 9264' 9 9473 8521 28 TGPD TGE Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1 9080' H 4-1/2" SWS NIP, ID = 3.813" I 3-3/8" 4 9264 - 9310 0 01/04/93 I 3-3/8" 6 9735 - 9775 0 05/23/04 ' El ICI, 9130' H 9-5/8" X 4-1/2" BAKER D PKR, ID = 4.75" 3-3/8" 4 9795 - 9862 0 01/23/93 3-3/8" 4 9877 - 9975 0 01/22/93 3-3/8" 6 9880 - 9890 0 05/23/04 I I 9161' 1-1 4-1/2" SWS NIP, ID = 3.813" 1 3-3/8" 6 9920 - 9950 0 05/22/04 3-3/8" 6 10005 - 10025 0 05/22/04 3-3/8" 6 10035 - 10055 0 05/22/04 I 9261' H CARBIDE BLAST RINGS (9261'-9313') I 3-3/8" 4 10036 - 10056 0 01/22/93 I I TOP OF 7" LNR I-1 9506' Z I e 9620' H 7" X 4-1/2" BAKER SABL-3 PKR, ID = 3.87" 1 9-5/8" CSG, 47#, NT-80, ID = 8.681" H 9637' 1 -41 . I I 9651' H 4-1/2" SWS NIP, ID = 3.813" I a...ajP --, 6t7op5', - I I 9672' H 4-1/2" SWN NIP, ID = 3.725" I I 4-1/2" TBG,12,6#, 13 .0152 bpf, ID = 3.958" I-1 9685' 1—' I 9685' H 4-1/2" TUBING TAIL, WLEG, ID = 3.95" I I, 9686' I—I ELMD TT LOGGED 01/22/93 I I I I I PBTD 1-1 10408' I 7" LNR, 26#, CR-13-80..0383 bpf, ID = 6.276" I—I 10500' I /I OA A At AV DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY uNn 10/30/92 ORIGINAL COMPLETION WELL: P1 5/22-5/23/04 MJA/KK ADPERFS PERMIT No: r 1920940 08/04/04 GRC/TLP SURF CSG CORRECTION API No: 50-029-22288-00 05/29/06 DFR/DTM CSG CORRECTIONS (11/24/04) SEC 16, T12N, R14E, 4104.8' FEL & 279.74' FNL BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~ ~Y~ ~~~` ~ ~~~C Mr. Tom Maunder ~ ~ Q Alaska Oil and Gas Conservation Commission ~ a 333 West 71h Avenue r Anchorage, Alaska 99501 ~ ~ -M ~(~ Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator i • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA o NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-OS 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-06 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-08A 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA 6.80 7/7/2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7!6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair WellD Pluq PerforationsD Pull Tubing D Perforate New Pool D Operation Shutdown D Perforate [K] 4. Current Well Class: Stimulate 0 OtherD WaiverD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 192-0940 Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 50.80 8. Property Designation: ADL-028297 11. Present Well Condition Summary: Total Depth Development ŒJ Stratigraphic D 9. Well Name and Number: P1-20 10. Field/Pool(s): Pt Mcintyre Oil Field 1 Pt Mcintyre Oil Pool Exploratory D Service D 6. API Number 50-029-22288-00-00 measured 10500 feet Plugs (measured) None Effective Depth true vertical 9452.7 feet Junk (measured) None measured 10408 feet true vertical 9368.8 feet Casing Conductor Liner Production Surface Surface Length 73 1006 9596 85 3349 Perforation deDth: Size 20" 91.5# H-40 7" 26# 13CR80 9-5/8" 47# NT-80 13-3/8" 68# K-55 13-3/8" 68# L-80 MD TVD Burst Collapse 43 116 43.0 116.0 1490 470 9494 - 10500 8539.0 - 9452.7 7240 5410 41 - 9637 41.0 - 8667.5 6870 4760 40 125 40.0 125.0 3450 1950 125 - 3474 125.0 - 3473.5 4930 2270 Measured depth: 9735 - 9775,9795 - 9862,9877 - 9880,9880 - 9890,9890 - 9920,9920 - 9950,9950 - 9975 '¡.K¡r 10005 -10025, 10035 -10036,10036 -10055, 10055 -10056 ¡¡;;I:::.f'r=: " True vertical depth: 8756.95 - 8793.47,8811.72 - 8872.81, 8886.48 - 8889.22,8889.22 - 8898.33, 8898.33 - 8925.¿4,~~~j~i£:() 8952.92 - 8975.64,9002.88 - 9021.02,9030.09 - 9031,9031 - 9048.23,9048.23 - 9049.14 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 37 9685 4:j r.; . - J n 1)n.14 A§¡.. ' ~. ~tao!& ~3Bs ~ . , ' 'I ~E;, ({'¡~" Imdb~e ' 'UJ~,¡lðb~b:1 Packers & SSSV (type & measured depth): 4-1/2" Baker D Packer 4-112" Baker SABL-3 Packer @ 9130 @ 9620 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 4.1 8446 2250 4.8 5592 2300 13 Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Oil-Bbl 1407 1005 Tubing Pressure 752 1106 15. Well Class after proposed work: Exploratory 0 Development ŒJ ServiceD 16. Well Status after proposed work: Oil]] GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Daily Report of Well Operations! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Garry Catron ~~r¡y Catron i1~ Cc1k~ 8/4/04 Form 10-404 Revised 4/2004 Title Production Technical Assistant Phone 564-4657 Date ~~~ AUG 1 Å Z"U~ ( P1-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/07/04 ***WELL FLOWING UPON ARRIVAL***. DRIFT W/ 3-3/8" DUMMY GUN. TAG SOFT BTM @ 10270' SLM + 23' CF = 10293' ELM.. 23T OF RAT HOLE. OPEN PERFS FROM 9264' MD TO 10056' MD. RDMO.. ***WELL FLOWING UPON DEPARTUREu* OS/22/04 Perforate 9920'-9950' 6 SPF, 10005'-10025' 6 SPF, 10035'-10055' 6 SPF FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL Page 1 TREE = WELLHEA 0 = AClUA TOR ;' KB. 8.BI = BF. 8.EV = KOP= Max Angle = Datum MD = Datum lVD = FWC em 011S 50.8' 3977' 38 @ 8869' 9838' 8800' SS 10-314" CSG, 45.5#. L-80.ID = 9.953" H 3500' Minimum ID = 3.725" @ 9672' 4-1/2" PARKER SWN NIPPLE PffiFORA TION SUWMARY REF LOG: DlLlGR ON 10/29/92 A NGLE AT TOP ÆRF: 32 @ 9264' f\bte: Refer to A'odUCbon DB for historical perf data SIZ E SPF INTER\! AL OpnlSqz DA TE 3-3/8" 4 9264 - 9310 0 01104/93 3-3/8" 6 9735 - 9775 0 05123/04 3-3/8" 4 9795 - 9862 0 01123/93 3-3/8" 4 9877 - 9975 0 01122/93 3-3/8" 6 9880 - 9890 0 OS/23/04 3-3/8" 6 9920 - 9950 0 OS/22/04 3-3/8" 6 10005 - 10025 0 05122/04 3-3/8" 6 10035 - 10055 0 OS/22/04 3-3/8" 4 10036 - 10056 0 01122/93 1 TOPOF7" LNR 1-1 9506' 9-5/8" CSG. 47#. NT-80. 10 = 8.681" 1-1 9637' P1-20 @) r4 L I :8: g I L D L r-- L ~ :8: ¡-4 1 14-1/2" TBG.12.6#. 13CR-NSCT. 0.0152 bpf. 10 = 3.958" l-f 9685' t---' 1 PBm 1-1 10408' 1 ~. 7" LNR. 26#. CR13-80. 0 0383 bpf. 10 = 6.276" 1-1 10500' ~^^^& DA TE REV BY COMMENTS 10/30/92 ORIGINAL COMPLETION 08/12/01 RNlRP CORRECTIONS 5/22-5/23/04 MJA/KK ADÆRFS DA TE REV BY COMM8\JTS . SA FETY NOTES' 1UBING HANGER: FMC IV @ 22' MD. 1983' H 4-1/2" CAWCOTRDPSSSV .10 = 3.812" 1 GAS LIFT MA NDRELS OBI TYPE VLV LATCH PORT [)A. TE 2 TGPD TG 36 TGPD TG 36 TGPD TG 37 TGPD TG 38 TGPD TG 38 TGPD TG PROCXJCTION MA NDR8.S OBI TYPE VLV LATCH PORT DATE 36 TGPD TG 29 TGPD TG 28 TGPD TGE ~ ST MD lVD 1 3538 3537 2 5689 5476 3 6888 6446 4 7542 6971 5 8272 7554 6 9039 8159 ST MD lVD 7 9186 8277 8 9440 8492 9 9473 8521 9080' 1-1 4-1/2" SWS NP. 10= 3.813" 1 1-1 9-5/8" X 4-1/2" BAKffi 0 PKR. ID = 4.75" 1 1-1 4-1/2" SWS NP. 10 = 3.813" 1 9130' 9161' 9261' 1-1 CARBIDE BLAST RINGS (9261'-9313') 1 9620' 1-1 7" X 4-1/2" BAKER SABL-3 A<R 10 = 3.87" 1 .. 9651' 1-1 4-1/2" SWS NP. 10 = 3.813" 1 9672' 1-1 4-1/2" SWN NP, 10 = 3.725" 1 9685' - 4-1/2"lUBINGTAIL, WLEG.ID -:: 3.95" I 9686' - EU..1D TT LOGGED 01/22/93 I FRUDHOE BA Y UNIT W8.L: P1-20 ÆRr\,IIT No: 92-094- API No: 50-029-22288-00 Sec. 16. T12N, R14E 4104.8 FB.. 279.74 FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Julie Heusser,"~'~\~ 'x z~' ,~,~\/t)~ DATE: Commissioner Tom Maunder, ~~~$UB~CT P. I. Supervisor ~,[ ~*," ~ \ : John H Spaulding, Petroleum Inspector April 10, 2001 SVS Tests BPX PBU LGI & PM-O1 April 11, 2001: i traveled to BPX's Lisbume Gas Injection (LGI) and also on to the Point Mcintyre PM-01 location to witness Safety Valve Testing. The AOGCC SVS test reports are attached for reference. As noted 3 failures were observed on both pads; with 2 being repaired and retested immediately. The third failure asssv and will need further attention. Mark Wysocki, lead operator was training 2 new hires. The crew did an excellent job. Summary: I witnessed the SVS tests on LGI and PM-01 LGI, 3 wells, 9 components, 1 failure, 11% failure rate PM-01, 11 wells, 33 components, 2 failures, 6% failure rate Attachment; Svs bpx Igi 4-10-01js Svs bpx prn-0! 4-10-01js Non Confidential Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: M~,,,k WYsocki AOGCC Rep: John H.~ Spaulding Submitted By: John~ Spaulding Date: Field/Unit/Pad: ,,,Pt, Mdntyre/PBU/pM-01 Separator psi: LPS 460 HPS 4/9/01 i i . . i ii i . ii i i I ~ i .i i ii ii iii i ii . .i i ii i I t i ii i i ii We~ Pemit Separ Set L~ T~t Test Test Date [ Oil, WAG, G~J, Nnmber, ,,Nnmber ..... PS! , PSi T~p, C~de Code Code Passed G~rCYCLE 12 1910370 886oso ....................................... P1-03 1890130 " 460 " 550 ' " 310: P ' P P .... 0IL Pl-O4 i93063'0 46'0 ..... 700 700~" 'P' P- ' P ............... OiL P1-05 1930870 460 350 300: P P 9 OIL ..... , . , P1-06 1961370 460 700 675~ P P P OIL , i89 3 o .................................... P1-08 1930980'" 460 1500 ....... i200 " 'P' P' "~ ..... oiL Pi-09" 1961540 4~ 350 300 P P ' P .... OIL PI-11 1920860 460 350 250 P P P OIL ,.,., , ,,.,,, ,,, . , ,, , , . Pl-12 1910130 pl'i3 1930740' '460 ' 15'o0 .... 1'150 P ..... P e ........... OIL ,.~, ,, , ,, , , , , ,,. ~ .... Pl-17 1930510 460 350 280 P P P OIL [.. p!-20', .... I'92o940' '" ~6o 3}o 175 ' 3 p p 4/9'/Ol " 'OIL , , , , ., ,. . , , , ,. . , , t .... ., PI-23 1961240 ,, , .~ . , , , , ., , , ,.. P1-24 1961490 P1-G1 ...... i92115'0 "' 3600 2900 ' '2850 P P' ' ' P ....... GmJ , , , ,,, ............ , ...... ,, . , , , , , , ,, , ,, , ,,, , , , ,, , , , , , , Wells: 11 Components: 22 Failures: 2 Failure Rate: 0.09% [-190 Day Remarks: p !,,-08 & P 1.-3. were c..hoked' .b[t..ck,. hence t.he.' .higher. pilot settings ............ P 1-20 pilot reset and retested RJF 1/16/01 Page 1 ofl 010409-SVS PM-01 PBU-js Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: ~k Wy,socki ~ AOGCC Rep: J0,.h~,, ~:,Spa,uldhg Submitted By: John Spauldhg Field/Unit/Pad: Lisburne/PBU/LGI Separator psi: LPS Date: 4/9/01 ' HPS . · Well Permit Separ Set L/P Test Test Test Date oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE_ LGi-02 1861400 3800 2900 2300 ~.~3 P P 4/9/01 GINJ LGI-04 1880130 LGI-06 1860670 3800 2900 2500 P P P " GINj' ~GI-0'8 '1860550 ........ ' ~" LGI-i'0 1860690 3800 2600 2300 'P ....P P GINJ LGI- 12 1860540 Wells: 3 Components: 6 Failures: 1 Failure Rate: 16.67oA~ 90 Day :. : _ . ,, ,, , , ,., . ,, , ,., , ~ Remarks: . LG!-02.Pilot tripped to low and was reset-retested and ,.pS. s.s~ RJF 1/16/01 Page 1 of 1 010409-SVS LGI Lisbume-js ON OR BEFORE c:LO~LM.D°c PERMIT 99-094~ . 92-094 92-094 92-094 92-094 92-094 92-094 92-094 92-094 92-094 92-094 92-094 92-094 92-094 92-094 9~-u94 92-094 92-094 92-094 92-094 92-094 92-094 92-094 9 ~ c'~ ~-~94 92-094 92-094 92-094 DATA ~OGCC Individual Well Geological Materials Inventory T DATA_PLUS CORE CHIPS CORE ANALYSIS BHC/MAC/CSC BHP CDN CDN/TVD CDR CDR/TVD COMP DIL/GR EPM GCT GR MAC/AC/FWF MAI/GR/CR MUD (IFM) MUD (IFM) PFC PRESS C 9705-10238 SS#860 D 9655.05-10238 DISKETTE D DIRECTIONAL SURVEY L 9075-10000 L 9640-10430 L 9640-10503 L 8600-9400 L 7086-10503 L 6600-9450 TVD L 9490-10353 L 9640-10461 L 6500-10500 L 40-10371 L 9150-9466 L 9075-10000 L 9050-10484 L 92520-12925 TVD L 9520-12925 MD L~ 9150-9466 L 6250-9500 PROD/FBS/TEMP/PR L 9000-10100 SBT L 7072-10385 SSTVD ZDL/CNL/GR/CAL 407 CORE ANALYSIS FINAL WELL RPT GCT L 9640-10461 L 6500-10430 R COMP DATE: 11/02/92 R 9655.05-10238 R 10/13-10/28/92 R 0.00-10500 Page · i Date- 11/02/94 RUN DATE_RECVD -- 02/05/93 06/07/93 1 12/31/92 1-2 12/31/92 1 12/31/92 COMP 12/31/92 COMP 12/31/92 COMP 12/31/92 COMP 12/31/92 1 04/14/93 1 12/31/92 1 04/14/93 1 12/31/92 1 04/14/93 1-2 12/31/92 1 12/31/92 1 04/14/93 1 04/14/93 1 04/14/93 1 04/14/93 '1 03/11/94 1 12/31/92 1 12/31/92 1 12/31/92 02/04/93 06/07/93 06/07/93 1 02/04/93 .-,OGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA_PLUS Page · 2 Date - 11/0'~'/94~ RUN DATE_RECVD 92 - 094 SURVEY 92-094 DRY DITCH 92-094 5493 92-094 5494 92-094 5495 Are dry ditch samples Was the well cored? R 3428-10435 MWD S 6460-10500 T 7086-10503 OH/LWD T 3501-11000 ANADRILL ADVSR 1-3 T 8970-10495 MAC WAVEFORMS 1-2 required? no And received? (~es~ & description received? Are well tests required? yes no Received? Well is in compliance COMMENTS Initial yes no 02/04/93 11/20/92 12/31/92 12/31/92 12/31/92 no Well Name 'P2-30 P2-30 P2-30 P242 P242 P2-42 P2-42 P2-51 -51 Data Description FINAL LOG:~Compensated Neutron Log (Dual / Porosity - CNT-G) Run # Date Run ~ 1/8/94 FINAL LOG: D~ual Burst TDT-P (~ 1/8/94 1/17/94 "FINAL LOG: Perf Record 3 3/8 .... HJII, 6SPF"__ "FINAL LOG: Perf Record 270'3 3/8 .... 6 SPF" /~IS Tape:d~Wl./CN/ZDL_~.~: 7500-10564 w/lis verification FINAL LOG: V'~ement Bond Log (CBT-GR) FINAL LOG: Cement Evaluation Log (CET-GR) Company Schlumberger Schlumberger Schlumberger 1/16-17/94 Schlumberger 1/9/94 Atlas V'Compensated Neutron Log (Dual Porosity - CNT-G) 1/15/94 Schlumberger fi -lt bq 5 't~ual Burst TDT-P Log 1/15/94 Schlumberger qg~" tv~$(c ~" (~) 1/11/94 Schlumberger l~,~cr- I'b~ ~" 1/11/94 Schlumberger Please sign and return to: Elizabeth R. Barker, ATO-415 ARCO Alaska, Inc. ~ P.O. Box 100360 ~ff~ Anchorage, Alaska 99510-0360 t' ~e,Oo ' PLEASE SIGN ONE COPY AND RETURN Transmittal Number: 703 Page: 2 ., STATE OF ALASKA ALASK OIL AND GAS CONSERVATION CL,,ClMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG OIL [] GAS [] SLISPENDED [] ABANDONED [] SERVICE [] 12. Name of Operator 7, Permit Number ARCO Alaska, Inc. 92-94 . 3'. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-22288 4. Location of well at surface ~ ....5"* 9. Unit or Lease Name 1384' NSL, 908' WE& SEC. 16, T12N, R14E, UM 1 "'.~.~"~:~ Point Mclntyre ¢ ?~'.'~?' t 10, Well Number At Top Producing Interval };'-i';!i,,/¢;' ;:;'i;'.;;'? 11. Field and Pool At Total Depth. ' ~ ..... ":'""~"~ ..... '~ Point Mclntyre 440' SNL, 1475' WEL, SEC. 5. Elevation in teel (indicate KB, DF, etc.) I· ~g i and Serial No. KBE = 50.8'I ADL 28297 12. Date Spudded 13. Dae T.D: Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if oflshore 116. No. of Completions 10/8/92 10/28/92 11/1/92J N/A feet MSL! Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDi 19. Directional Survey FO. Depth where SSSV set ~21. Thickness of Permafrost I 0500' /~,D/ 9.~,,3 TVD 10408' MD/9369' TVD YEs [] ~0 [] 1978' feet MD ~1 Approx. 1750' I 22. Type Electric or Other Logs Run Run # 1GR/ON/ZDL~IFL Run # 2 MAC/GR 23. CASING, LINER AND CEMENTING ~ORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEM~ RECORD AMOLJNT PUl 20" 91.5# H-40 Surface 73' 30" 11 yds Arcticset 13-3/8" 68# L-80 40' 3474' 16" 3837 cuft PF "E"/449 cu ft C/ass "G" 9-5/8" 47# L-80/NSCC 41' 9637' 12-1/4" 1144 cu ft C/ass 7" 26# 13CR80 41' 10500' 8-1/2" 211 cuft C/ass "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBff,~3RECORD interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diarneter 3-3/8" 4 spf MD TVD 4-1/2" 130R 9684' 9730'& 9621' 9264;9310' 8290'-8329' 9795;9862' 8761'-8822' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 9877'-9975' 8835'-~925' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10036; 10056' 8980;8998' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Not yet on p/~oduction I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL :GAS-MCF WATER-BBL CHOKEE4ZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure 3ALOULATED OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY-APl (corr) !Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of iithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Core description previously submitted. ; ~" .... .,¢'~ i~'i~ ':~, "" i~i ~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKER, ..~[MAT~ TESTS NAME ...... Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Colville Group 6990' 6528' HRZ 9491' 8536' Kalubik 9603' 8637' Kuparuk 9651' 8680' ~iluveach 10389' 9351' -. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Drilli, o Enoineer Suoervisor 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 spaces 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 §tate in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separ~ttely produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 A Lilt(>n / Dresser Company ARCO ALASKA, INC. ~(~!~ANALY S I S REPORT Pt. McINTYRE NORTH SLOPE, ALASKA CL FILE NO. BP-3-1485 Performed by' Core Laboratories 8005 Schoon St. Anchorage, AK 99518 (907) 349-3541 Final Report Presented February 24, 1993 These analysis, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories (all errors and omissions excepted); but Core Laboratories and it's officers and employees assume no responsibility and make no warranty of representation as to the productivity, proper operations, profitability of any oil, gas or other mineral well or formation in connection with which such report is used or relied upon. 8005SchoonStreeLAnchorage, Alaska 99518-3045, (907) 349-3541 Fax /t:~0/) 344 282:~ INTRODUCTION Core Laboratories was requested to perform a core analysis study on behalf of Arco Alaska, Inc. for samples recovered from the Point McIntyre P1-20 well from the North Slope, Alaska. Presented herein are the results of this study. Conventional cores cut with an oil based mud were processed on site by Core Laboratories and ARCO personnel. A service description and methodology are presented in section 1. The core analysis results and lithological descriptions are presented in section 2. A statistical summary and plot are presented in section 3. Appendices can be found in section 4. In conjunction with the report, the tabular results of the analysis are supplied on a IBM compatible diskette. We sincerely appreciate this opportunity to be of service and hope this data prove beneficial in the development of this reservoir. TABLE OF CONTENTS Section 1 2 3 4 5 CONVENTIONAL CORE ANALYSIS, SERVICE DESCRIPTION CONVENTIONAL CORE ANALYSIS, TABULAR RESULTS CONVENTIONAL CORE ANALYSIS, STATISTICAL AND CORE GAMMA DATA APPENDIX DATA DISKETTE SECTION 1 CONVENTIONAL CORE ANALYSIS SERVICE DESCRIPTION SECTION 1 CONVENTIONAL CORE Fi el d Procedures Conventional coring equipment in conjunction with a oil based drilling fluid was used to extract core samples during October of 1992. All cores were taken using aluminum inner core barrels. Core Laboratories' field personnel assisted with core preservation and handling. Sample points for plugging at Anchorage and disposition of the core was conducted according to ARCO's instructions. A summary of these procedures can be found in the appendix. Core Lab Personnel Functions 1. Set up and preparation of core trailer, supplies, and equipment. 2. Caught and prepared core for movement from rig floor to core trailer. 3. Fitted together core, marked depths, assisted with the selection of samples. 4. Wrapped, dipped, and boxed preserved core pieces. Core Handlinq and Preservation by Core Lab Personnel Core Lab representatives were present on the rig floor when the core barrel was disconnected. They ensured that the core was kept in proper order and covered to minimize exposure to the atmosphere during transport to the core trailer. The cores, which were contained in aluminum inner core barrels, were taken to the pipe shed, depth marked and double striped, and cut into three foot sections with tubing cutters. The ends of the sections were then rubber capped and clamped. These sections were taken to the core trailer. Upon arrival of the core at the core trailer a Core Lab representative removed the core from the inner barrel and fit the core together. The core was oriented with the apparent up-dip at the top, and marked. Sample intervals were marked on the core at the wellsite. A three inch section near the foot mark was marked "SC", and a plug sample site was marked on the end nearest the foot mark. No "SC" sample site was allowed within one inch of a fracture in the core. Additional sample sites, designated as "R", were chosen from some intervals not already chosen using the "SC" criteria. Once the samples were designated and marked the entire core was wrapped using Saran Wrap and foil. Then it was dipped in CoreSeal. The core was placed in boxes which were marked, taped, and stacked for shipment to Core Laboratories' Anchorage facility. Please refer to the appendix for a more complete description of the wellsite procedures. Conventional Core Processing ~n Anchorage Upon arrival at Core Laboratories~ Anchorage facility, the preserved core pieces were removed from their boxes, placed in depth order, and surface core gamma logged one core at a time. After core gamma logging, the "SC" and "R" samples selected at the wellsite were depreserved and 1.5 inch horizontal plugs were drilled with hexadecane. Were possible, additional plugs were taken from non-wellsite selected intervals to provide a more complete data set. All plugs were immediately loaded into the Dean-Stark apparatuses or, if no Dean Stark units were available for immediate use, were wrapped in Saran Wrap and aluminum foil, placed in jars, and stored chilled. The remaining whole core was then rewrapped in Saran Wrap and foil, and dipped in CoreSeal. The sampling completed, the core was depreserved 10 feet at a time, oriented with the top of the bedding up, and slabbed 1/4 and 3/4. The 3/4 slabbed sections were immediately represerved with Saran Wrap, foil, and CoreSeal. The 1/4 sections were washed with fresh water and allowed to dry for viewing and photography. A more complete description of the core processing procedures can be found in the appendix. Core Photographs Approximately 15 feet of the cleaned 1/4 slabbed sections appears in each photograph. Six sets of visible spectrum flash and six sets of ultraviolet light photographs appear in separate binders. Conventional Analysis Techniques Core analysis methods as specified by ARCO were used throughout the sampling process. Several changes to the procedures were instituted during the process, as noted below. Cutting and Trimminq Core Plu~qs, page 11-13 Original: Calls for placing sample numbers on plug and end pieces. Change: Given the oil mud and chosen solvents, placing marks on the plugs and end pieces would be impractical and/or potentially damaging to the analysis. Foil was labeled for plugs waiting to be loaded into the Dean Stark units. Once unwrapped, the sample bags (and thimbles after Dean Stark analysis) were marked and separate labels were placed with the samples from station-to-station until the samples were dry. At that point, numbering was applied to the sample. Plug ends were placed in numbered bags. Original' Refers to the chloroform-methanol cleaning equipment as Dean Stark gl assware. Change: While a few Dean Stark glassware units were used for this step, most samples were cleaned in Dean Stark units made, predominantly, of metal. These systems were approved by ARCO. To assess solvent color, an aliquot was removed and observed in a 250 ml glass beaker. If dirty, the solvent in the boiling chamber was replaced. This was done almost daily, until clean solvent was observed. Original' Calls for cleaning in the chloroform-methanol equipment until clean solvent was observed. Change: Because of time constraints ARCO authorized removal of partially cleaned samples from the cleaning units to allow other samples to be processed in a more timely manner. Thirty eight samples (as noted in the table below) were removed from the cleaning units before the cleaning was completed. These samples were otherwise analyzed in the normal fashion. Twenty sample had permeability greater than the five millidarcy cutoff specified by ARCO for recleaning. These samples were returned to a cleaning apparatus for further cleaning, and reanalyzed. Samples below the cutoff were not reanalyzed; and broken, fractured, or poorly consolidated samples with significant grain loss were not considered suitable for further cleaning. The samples 3-32, 6-15, and 7-33 were not completely cleaned during the second run. The cleaning of these three samples was terminated at the request of ARCO. Partially Cleaned Samples Removed From Cleaninq Units Core Sample Depth Permeability Days Cleaned Days Cleaned (mds) 1st Run 2nd Run 3 27 9790.05 20.23 40 Not Suitable 3 32 9795.05 10.75 42 54 3 38 9801.05 9.14 41 10 3 39 9802.25 27.67 41 Not Suitable 3 40 9803.05 3.34 41 Below Cutoff 4 3 9825.05 9.34 41 10 4 4 9825.95 NA 40 Not Suitable 4 8 9830.05 163.09 40 Not Suitable 4 12 9834.05 77.60 41 10 4 15 9837.05 153.12 40 25 4 16 9838.20 32.94 41 26 4 17 9839.05 21.87 40 19 4 39 9861.20 18.44 40 22 4 42 9864.25 35.45 40 Not Suitable 4 43 9865.05 3.13 41 Below Cutoff 5 10 9892.05 472.18 40 10 6 14 9954.05 49.88 39 Not Suitable Core Sample Depth 6 15 9954.95 6 18 9958.05 6 36 9976.05 7 7 10007.05 7 8 10008.05 7 16 10016.25 7 20 10020.05 7 24 10024.20 7 25 10025.25 7 29 10031.20 7 33 10035.05 7 34 10036.05 7 35 10037.05 7 36 10038.05 7 38 10040.15 7 44 10046.05 7 55 10057.05 7 56 10058.05 7 58 10060.00 7 76 10078.00 8 48 10139.80 8 62 10158.00 Permeability Days Cleaned Days Cleaned (mds) 1st Run 2nd Run 26.95 39 54 37.23 39 19 0.28 37 Below Cutoff 26.28 37 Not Suitable 52.72 37 10 68.51 37 16 0.44 29 Below Cutoff 0.79 37 Below Cutoff 7.00 37 10 0.40 37 Below Cutoff 35.31 37 54 79.25 37 19 32.04 37 22 9.80 37 38 NA 37 Not Suitable NA 37 Not Suitable 5.91 37 19 2.02 37 Below Cutoff 68.14 37 Not Suitable 17.50 37 10 108.94 37 10 2.66 37 Below Cutoff Procedures For Poorly Consolidated Samples At the wellsite it was determined that 21 feet of core seven from 10,009 ft. to 10,030 ft. was poorly consolidated and not suitable for sampling in the normal manner. The service company samples were selected and preserved in the normal manner. The "SC" samples from this portion of the core were then frozen and shipped to Anchorage. In Anchorage the frozen section of core received from the wellsite were placed on dry ice and retained for sampling after work was completed on the remaining core. Following instructions provided by ARCO personnel - a copy maybe found in the appendix - frozen plugs were drilled with liquid nitrogen and trimmed on a saw, dry. The still frozen plugs were then wrapped in Teflon tape and lead foil with a 120 and 60 mesh screen at each end. Before loading in the Dean-Stark equipment a seating pressure of 1000 psi was applied to secure the mount, then the samples were weighed and the standard procedures were followed for fluid extraction and drying. After a stable dry weight was obtained for a sample its pore volume and permeability were measured using the overburden confining pressure of 2,581 psi. Following the pore volume measurement the samples were desleeved and a grain volume measurements made using standard procedures for the Extended Range Helium Porosimeter. The overburden porosity was calculated using equation (1). P : lO0(Vp/(Vp + Vg)) (1) Where: P = Porosity, Percent Vp = Pore Volume Vg = Grain volume Results from these poorly consolidated samples are in a separate table following the results of the consolidated samples. Dean-Stark Fluid Saturation Measurements Water was extracted from the samples by the Dean-Stark technique using toluene in cleaned apparatuses. Fresh commercial grade toluene was used for each extraction and the equipment was cleaned between each sample as directed by ARCO. Extraction continued until no change in water volume was observed over a four hour period. Minimum extraction time was twelve hours. Toluene remaining in the Dean Stark flasks was recovered for chemical analysis. Samples were removed from the water Dean-Starks and placed in cleaning Dean Stark units containing 87 volume% chloroform - 13 volume% methanol cleaning solution. Cleaning continued until the cleaning solution showed no crude oil color. Extracted samples were dried in a 180 degrees F. vacuum oven for a minimum of 24 hours and until sample weights were constant to 0.01 grams over a four hour drying period. Samples were cooled in a desiccator to room temperature before porosity and permeability were measured. Saturations by Dean-Stark methods were calculated using Equations 2 and 3. Equation 2a was used for samples which were cleaned twice. So : [((W1 - W2 - H20)/Do)/Vpc] x 100 (2) So : [(((W1 - W2 - H20)/Do) + Vo2)/Vpc] x 100 (2a) Sw = [H20/Vpc] x 100 (3) Where: So = Oil Saturations, Percent Sw = Water Saturation, Percent W1 : Natural Weight W2 : Extracted and Dried Weight H20 : Extracted Water, Density Assumed 1.0 gm/cc Do : Density of Oil, .85 gm/cc Vpc : Pore Volume, Corrected for Grain Loss (see below) Vo2 : Oil Volume Extracted During the Second Cleaning Run (see Equation 3d) Corrections for grain loss were applied to the water and oil saturation calculations. The corrections were made using equation 4a and 4b. Vpc : Vp x [(W2 + Wgl)/W2] (4a) Where' Vpc = Corrected Pore Volume Vp = Measured Pore Volume of Dried, Clean Sample W2 = Extracted and Dried Weight of the Sample Wgl = Weight of the Grains Lost During the Process Wgl = Wpb - Wb - W2 (4b) Where' Wgl = Weight of Grains Lost During the Process Wpb = Dry, Stable Weight of the Plug plus the ARCO Prescri bed Bag W2 = Extracted and Dried Weight of the Sample Grain Loss Correction For Recleaned Samples As previously noted, twenty of the partially cleaned samples had a permeability in excess of 5 millidarcies and therefore required a second cleaning until completely cleaned. The total grain loss for both cleanings, as calculated in Equation 4c, was substituted for the value calculated for the first cleaning. WglT = Wgl + W2 - Wp + Wpt - Wth - W2T (4c) Where- WglT = Total Grain Loss from Both Cleanings Wgl = Weight of Grains Lost from the First Cleaning W2 : Extracted and Dried Weight from the First Cleaning Wp : The Dried Weight before the Second Cleaning Wpt : Stable Weight of Plug and Thimble after the Second Cleaning Wth : Dry Weight of the Thimble before the Second Cleaning W2T = Extracted and Dried Weight of the Sample after Completion of the Second Cleaning Additional Oil Volume Correction For Recleaned Samples The second cleaning extracted additional oil from the samples. This volume, calculated using Equation 4d, was added to the oil volume derived during the first cleaning, and the total was applied to pore volume as in Equation 2a. Vo2 = (Wp + Wth - Wpt)/Do (4d) Where' Vo2 = Volume of Oil Extracted During the Second Cleaning Wp = The Dried Weight before the Second Cleaning Wth : Dry Weight of the Thimble before the Second Cleaning Wpt : Stable Weight of the Plug and Thimble after the Second Cleaning Do : Density of Oil, .85 gm/cc Grain Density ~-, ~ ~ ~ ~..~ .~ Grain volume determinations were measured on all samples according to Boyle~s Law utilizing the Extended Range Helium Porosimeter. The equipment was calibrated to yield a grain density variation of less than .005 gm/cc. Grain densities were calculated using Equation 5. Dg : Mg/Vg (5) Where: Dg : Grain Density Vg = Grain Volume Mg = Grain Mass Atmospheric Porosity of Consolidated Samples The horizontal plug samples were measured for bulk volume by mercury displacement at ambient conditions. Porosity was calculated using Equation 6. P : r(Vb-Vg)/Vb)] x 100 (6) Where: P : Porosity, Percent Vb : Bulk Volume Vg = Grain Volume Atmospheric Permeability to Air Horizontal permeabilities were measured in a Hassler type core holder at a confining pressure of 400 psig after the plugs were cleaned in a sonic cleaner and redried. Permeability calculations were performed as defined by Darcy~s Equation for compressible fluids, Equation 7. Where: Pa x v x 1000 Qa x L x L K = x (7) (P1 - P2)(P1 +P2) Vb K = Permeability v = Gas Viscosity P1 - P2 = Differential Pressure P1 +P2 : Mean Pressure Pa = Atmospheric Pressure Qa = Flow Rate L = Length Vb : Bulk Volume Filtrate Saturation Tracer concentration in plug samples was calculated using tracer concentrations supplied by CPM Laboratories. Filtrate saturations were calculated using Equation 8. Sof: 100*(Wo*Ff/O.82)/Vp (8) Where: Sof = Saturation of Filtrate in Core (% pore volume) Wo : Weight of Oil Phase in the Core Ff = Weight Fraction of Filtrate in the Oil in the Core Vp = Pore Volume of the Core (cc's) Hexadecane Saturation Hexadecane saturations as a percent of pore volume was calculated using data provided by CPM Laboratories in Equation 9. Soh : (Wto*Cht)/(ph*Vp) (9) Where: Soh = Hexadecane saturation in % of pore volume Wto = Weight, in grams, of toluene after the Dean Stark procedure. ph = The density of hexadecane, .777 gm/cc Vp : Pore volume in cubic centimeters Corrected Oil Saturation An oil saturation with mud filtrate and hexadecane invasion removed using CPM Laboratories' data was determined using Equation 10. So corr : (So-Somf-Soh) (lO) Where: So corr = Corrected oil saturation in % of pore volume So : Uncorrected oil saturation Somf : Mud filtrate in core (Equation 7) Soh : Hexadecane saturation (Equation 8) Company : ARCO ALASKA, INC. Wel 1 .' P1-20 ANALYTICAL PROC CORE LABORATORIES Field : POINT MCINTYRE Formation : KUPARUK E DU R E S AND QUAL.I TY File No.: AR1485 Date : 24-FEB-93 ASSURANCE HA~IDLIN~ & CLEANING Core Transportation Solvent Extraction Equipment Extraction Time Drying Equipment Drying lime Drying lemperature AIR FREIGHT CLOROFORM/METHANOL DEAN STARK MINIMUM 24 HOURS CONVECTION/VACUUM OVEN MINIMUM 24 HOURS 180 DEGREES F. AMALYSIS Grain volume measured by Boyle's Law in a matrix cup using He Bulk volume by Archimedes Principle Water saturations by Dean Stark Oil saturations by weight difference in Dean Stark Permeabilities measured on 1.5 in. diameter drilled plugs Dean Stark grain densities clean, dry solid mineral phase are measured SECTION 2 CONVENTIONAL CORE ANALYSIS TABULAR RESULTS ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA CORE LABORATORIES FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERM EAB UTY POROSITY SATURATIONS GRAIN MUD ,,, T # # FT MD (%) % PvJ'% Pv ! % Pv / %Pv J % Pv GM/CC PPM ..PPM % DESCRIPTION / ] I 1 9655.05 20.23 20.5 56.8 54.2 40.0 2.7 0.0 3.27 0.000 29.900 0.220 SS- vwcmt,qtz,glau,sid, broken I 2 9656.05 7.83 18.4 42.6 42.6 50.6 0.0 0.0 3.23 0.000 29.900 ND SS-vwcmt,qtz,glau,sid,t pyr,frac I 3 9657.00 1.50 9.4 23.6 21.8 78.9 1.8 0.0 3.29 0.000 29.900 O. 133 SS- vwcmt,qtz,glau,sid,wh cht,frac I 4 9658.25 0.72 12.2 9.2 9.2 86.2 0.0 0.0 2.77 0.000 29.900 ND SS-wcmt, qtz,brn cly,glau,t pyr I 5 9659.25 1.39 14.0 10.3 10.3 84.4 0.0 0.0 2.71 0.000 29.900 ND SS-wcmt, qtz,glau,b~n clysr lith phi 1 6 9660.05 Broken 6.1 52.1 41.6 58.7 5.0 5.5 3.33 0.044 29.900 0.128 SS- vwcmt,qtz,glau,sid,brok en 1 7 9661.1 5 2.10 15.5 18.4 18.4 78.9 0.0 0.0 2.73 0.000 29.900 ND SS- wcrnt, qtz, glau,sid,occ wh cht 1 8 9662.05 1.72 15.2 20.8 20.8 70.4 0.0 0.0 2.72 0.000 29.900 ND SS-wcmt, cltz,gtau,brn cly,occ wh cht,broken 1 9 9663.05 1.94 15.8 19.8 19.8 70.2 0.0 0.0 2.71 0.000 29.900 ND SS-wcmt, qtz,glau,brn cly,occ wh cht~r 1 10 9664.25 0.87 12.6 18.1 18.1 79.0 0.0 0.0 2.71 0.000 29.900 ND SS-wcmt,qtz,glau,brn cly,occ wh cht,rr 1 11 9665.05 0.00 4.7 86.9 86.9 17.8 0.0 0.0 3.23 0.000 29.900 ND SS-vwcmt,qtz,glau,sid,t brn ch/ 1 12 9667.00 1.25 13.2 14.8 11,9 81.3 2.9 0.0 2.71 0.000 29.900 O. 167 SS-wcmt, qtz,gtau, br n cly,frac 1 13 9668.05 0.48 10.7 16.1 16.1 81.9 0.0 0.0 2.85 0.000 29.900 ND SS-wcmt,qtz,glau,brn cly,sid,wh arg gr 1 14 9669.05 0.79 13.5 16.7 16,7 79.2 0.0 0.0 2.70 0.000 29.900 ND SS-wcmt,qtz,gtau,brn cly,wh arg gr 1 15 9671.25 0.21 10.8 22.1 22.1 70.2 0.0 0.0 3.04 0.000 29.900 ND SS-vwcmt,cFz,glau,sid~r qtz 1 16 9672.05 5.27 10.9 13.1 13.1 84.2 0.0 0.0 2.96 0.000 29.900 ND SS-wcmt,qtz,glau,,gy cly,occ sid,rr lith pbi,frac 1 17 9673.05 0.41 12.8 22.3 20.6 67.0 1.7 0.0 3.35 0.000 29.900 0.126 SS-vwcmt,qtz,glau,sid~-r lith 1 18 9674.05 0.21 13.6 20.8 20.8 70.6 0.0 0.0 3.07 0.000 29.900 ND SS-vwcmt,qtz,glau,sid,occ wh cbt 1 19 9675.05 0.24 13.1 22.5 21.3 68.8 1.2 0.0 3.11 0.000 29.900 0.083 SS-vwcmt,qtz,glau,sid,wfl cmt 1 20 9676.20 0.21 10.4 18.4 18.4 79.1 0.0 0.0 2.92 0.000 29.900 ND SS-vwcmt,qtz,glau,sid,¢/cly,v~h cmt 1 21 9677.05 0.01 9.2 25.5 25.5 65.7 0.0 0.0 3.48 0.000 29.900 ND SS- vwcmt,qtz, glau,sid 1 22 9677.95 0.28 13.8 24.6 23.0 63.7 1.7 0.0 3.29 0.000 29.900 0.104 SS- vwcmt,qtz, glau,sid 1 23 9679.05 2.18 16.7 28.9 25.2 59.9 3.8 0.0 3.37 0.000 29.900 0.277 SS-vwcmt,qtz,glau,sidcrr cht pbl 1 24 9680.05 0.06 12.2 28.2 28.2 63.9 0.0 0.0 3.42 0.000 29.900 ND SS- vwcmt,qtz,glau,sid,wh cnt 1 25 9681.05 0.22 1 1.0 20.8 20.8 77.7 0.0 0.0 2.69 0.000 29.900 ND SS-wcmt,qtz,¢au,ck gy cly,wh cmt *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIM E CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. PI-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERM F_..AEI UTY POROSITY SATURATIONS GRAIN MUD CORE SMPL DEPTH KAIR (HEUUM) OIL coR'OI HEXAD. FILTRA. DENSITY TRACER TRACER HEXAD. #... #.. FT... MD (%) % Pv % Pv.1% Pv 1%Pv I % Pv GM/CC PPM PPM % DESCRIPTION ......... I 26 9682.05 0.07 10.5 27.2 27.2 62,7 0.0 0.0 3.12 0.000 29,900 ND SS-vwcrnt,qtz,gtau,sid,wh cbt I 27 9683.00 0.17 8.9 5.1 5.1 84.8 0.0 0.0 2.92 0.000 29.900 ND SS-vwcmt,qtz,ck gy cly,glau,wh cmt 1 28 9684.00 0.06 14.6 14.8 14.8 74.1 0.0 0.0 3.37 0.000 29.9(X:) ND SS- vwcmt,qtz, glau,sid 1 29 9685.05 0.82 17.7 20.1 18.1 66.2 2.0 0.0 3.22 0.000 29.900 0.153 SS- vwcmt,qtz,glau,sid 1 30 9686.05 0.64 16.3 17.2 16.2 64.5 1.0 0.0 3.27 0.000 29.900 0.072 SS- vwcmt,qtz,glau,sid,occ wh cht,vug 1 31 9687.05 0.39 11.6 20.7 20.7 71.8 0.0 0.0 2.91 0.000 29.900 ND SS- wcmt, qtz,glau,sid,wh crrrt I 32 9688.05 0.51 18.7 19.3 17.6 66.9 1.6 0.0 3.15 0.000 29.900 0.161 SS- wcmt, qtz,glau,sid,wh cht 1 33 9689.05 0.41 14.4 No Data 68.0 1.2 0.0 2.92 0.000 29.900 0.110 SS-wcmt,qtz,glau,sid,wh cbt 1 34 9690.05 0.43 16.1 18.5 16.9 64.1 1.6 0.0 3.24 0.000 29.900 0.134 SS- wcmt, qtz,glau,sid,wh cht 1 35 9691.05 1.1 0 16.9 35.5 33.0 48.1 2.5 0.0 3.24 0.000 29.900 0.232 SS-wcmt,qtz,glau,sid,tr wh cbt 1 36 9692.00 0.59 19,2 25.1 23.5 54.4 1.6 0.0 3.21 0.000 29.900 0.129 SS-wcmt, qtz,glau,sid,lt gy ~g gr I 37 9693.05 0.26 12.5 28.5 28.5 64.3 0.0 0.0 2.72 0.000 29.900 ND SS-wcmt,qtz,glau,(~ gy cly,wh cht 1 38 9694.05 0.19 10.5 20.7 18.8 71.2 1.9 0.0 2.70 0.000 29.900 0.104 SS-wcmt, qtz,glau,cl< gy cly,wh cbt 1 39 9695.05 0.44 16.0 30.7 28.4 54.6 2.3 0.0 3.13 0.000 29.900 0.170 SS-vwcmt,qtz,glau,sid,occ wh cht 1 40 9696.05 0.27 14.4 26.0 26.0 62.7 0.0 0.0 2.91 0.000 29.900 ND SS-vwcmt,qtz,glau,sid,occ wh cbt I 41 9697.05 0.27 13.7 25.5 25.5 66.0 0.0 0.0 2.89 0.000 29.900 ND SS-vwcrnt,qtz,glau,sid,occ wh cht 1 42 9697.95 0.21 11.4 20.1 20.1 74.4 0.0 0.0 2.83 0.000 29.900 ND SS-vwcmt,qtz,glau,sid,gy cly,occ wh cht 1 43 9703.05 0.09 10.3 8.0 8.0 80.7 0.0 0.0 2.72 0.000 29.900 ND SS-vwcmt,qtz,glau,gy cly,tr wh cht 2 1 9706.05 0.14 11.4 37,3 35.1 48.2 2.2 0.0 2.73 0.000 31.600 0.115 SS- vwcrnt,qtz, gy cly,occ glau 2 2 9707.05 0.07 10.2 32.8 32.8 58.3 0.0 0.0 2.78 0.000 31.600 ND SS-vwcmt,qtz,gy cly,glau,tr wh cht 2 3 9708.05 0.22 11.5 25.7 25.7 69.6 0.0 0.0 3.04 0.000 31.600 ND SS- vwcmt,qtz,sid, glau 2 4 9709.05 0.25 9.4 23.5 23.5 71.7 0.0 0.0 2.78 0.000 31.600 ND SS-vwcmt,qtz,glau,gy cly~r cbt 2 5 9710.05 0.10 10.2 18.2 18.2 77.9 0,0 0.0 2.74 O.(:X:X) 31.600 ND SS-wcmt,qtz,glau,gy cly~r lith pb~ 2 6 9712.05 0.11 11.3 24,7 24.7 68.5 0.0 0.0 2.77 0.000 31.600 ND SS-vwcmt,qtz,gbu,gy cty,occ wh cbt 2 7 9713.05 0.15 12.3 19.5 18.2 75.5 1.2 0.0 2.71 0,000 31.600 0.118 SS- vwcmt,qtz, glau,gy cly,occ wh cht ........... *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFERTO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERMEAEI LITY POROSITY SATURATIONS GRAIN MUD CORE SMPL DEPTH KAIR (HEUUM) OIL COR OI WATER EXAD'. # # FT MD (%) % Pv % PV [ % Pv .. % Pv .[ % Pv GM/CC PPM PPM % DESCRIPTION ................... 2 8 9715.25 Broken 5.1 34.5 27.9 55.4 6.6 0.0 3.48 0.000 31.600 0.185 SS- vwcmt,qtz, glau,sid,br ok en 2 9 9716.05 0.18 11.3 29.9 27.7 59.7 2.3 0.0 2.69 0.000 31.600 0.155 SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 10 9716.90 0.27 13.4 26.6 24.9 61.4 1.7 0.0 2.72 0.000 31.600 0.139 SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 11 9718.05 0.68 12.2 23.5 22.2 69.5 1.2 0.0 2.70 0.000 31.600 0.078 SS- vwcmt,q~z,glau,gy cly,occ wh cbt 2 12 9719.05 0.95 11.7 39.1 35.2 42.6 3.9 0.0 2.69 0.000 31.600 0.194 SS-vwcmt,qtz,glau,gy cly,occ wh cbt 2 13 9720.20 0.24 12.5 31.9 29.0 49.9 2.8 0.0 2.69 0.000 31.600 0.208 SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 14 9721.00 0.12 11.1 26.6 25.2 68.0 1.3 0.0 2.70 0.000 31.600 0.083 SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 15 9722.05 0.09 8.7 31.6 31.6 67.2 0.0 0.0 2.72 0.000 31.600 ND SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 16 9723.15 0.08 9.2 28.3 28.3 62.2 0.0 0.0 2.70 0.O00 31.600 ND SS-wcmt,qtz,gy cly,occ glau 2 17 9724.05 0.17 9.4 21.9 19.9 66.2 2.0 0.0 2.75 0.000 31.600 0.077 SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 18 9724.95 0.03 3.2 50.3 50.3 40.3 0.0 0.0 3.39 0.000 31.600 ND SS- vwcmt,qtz, glau,sid 2 19 9726.15 0.10 8.3 22.7 22.7 75.4 0.0 0.0 2.71 0.000 31.600 ND SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 20 9727.05 0.09 8.7 19.8 19.8 78.0 0.0 0.0 2.72 0.000 31.600 ND SS-vwcmt,qtz,glau,gy cly,occ wh cbt 2 21 9729.15 0.09 9.6 16.3 14.8 76.8 1.6 0.0 2.70 0.000 31.600 0.088 SS- vwcmt,qtz,glau,gy cly,occ wh cht 2 22 9730.05 0.23 11.1 23.8 23.8 70.8 0.0 0.0 2.72 0.000 31.600 ND SS-vwcmt,qtz,gtau,gy cly,occ wh cht 2 23 9731.05 0.21 10.9 28.6 26.1 59.4 2.5 0.0 2.69 0.000 31.600 0.144 SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 24 9732.25 0.01 2.3 94.0 94.0 19.5 0.0 0.0 3.39 0.000 31.600 ND SS-vwcmt,qtz,glau,sid,wh cly filled frac 2 25 9733.05 0.13 9.2 23.6 21.8 68.0 1.9 0.0 2.69 0.000 31.600 0.089 SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 26 9733.95 0.07 9.5 30.6 28.6 63.6 2.0 0.0 2.69 0.000 31.600 0.095 SS-vwcmt,qtz,glau,gy cly,occ wh cht 2 27 9736.05 0.15 10.7 27.4 25.3 65.6 2.1 0.0 2.69 0.000 31.600 0.1 O0 SS- vwcmt,qtz,glau,gy cly,occ wh cht 2 28 9737.05 0.26 11.1 28.9 25.1 51.3 3.8 0.0 2.69 0.000 31.600 0.200 SS-vwcmt,qtz, glau, gy cly 2 29 9738.05 0.24 11.1 34,3 34.3 61.3 0.0 0.0 2.72 0.000 31.600 ND SS-vwcmt,qtz, glau,gy cly 2 30 9739.05 0.12 8.9 22.9 22.9 72.3 0.0 0.0 2.69 0.000 31.600 ND SS-v'wcmt,qtz,glau,gy cly 2 31 9740.05 0.1 4 11.3 27.6 26.2 62.0 1.4 0.0 2.73 0.000 31.600 0.094 SS- vwcmt,qtz, glau,gy cly 2 32 9742.05 62.94 19.7 57.9 34.8 23.2 23.2 0.0 2.69 0.000 31.600 1.773 SS-vwcmt,qtz,glau,wh cht, occ brn cly *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAJLS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS .. DEAN STARK ANALYSIS PERMEAB UTY POROSITY SATURATIONS GRAIN MUD CORE SMPL DEPTH K,NR (HEUUM) OIL ~ORo! RLTRA. DENSITY TRACER TRACER HEXAD. # # FT' MD . . (%) .... j % Pv % Pv % Pv / % Pv 1% IN, GM/CC PPM PPM % DESCRIPTION ........... 2 33 9743.05 86.05 20.1 60.3 41.2 22.3 19.1 0.0 2.67 0.000 31.600 1.662 SS-vwcmt,qtz,glau,wh cht, occ brn cly 2 34 9744.05 106.18 20.1 60.3 38.4 20.9 21.9 0.0 2.67 0.000 31.600 1.748 SS-vwcmt,qtz,glau,wh cht, occ brn cly 2 35 9745.05 15.81 15.8 48.7 37.9 26.8 10.8 0.0 2.67 0.000 31.600 0.706 SS-vwcmt,qtz,glau,wh cht, occ br n c¥ 2 36 9746.05 7.57 15.1 41.0 33.0 41.1 8.1 0.0 2.68 0.000 31.600 0.564 SS-vwcrnt,qtz,glau,occ wh cht & brn cly 2 37 9747.05 0.15 9.7 29.4 27.4 62.1 2.0 0.0 2.69 0.000 31.6(X) 0.083 SS-wcmt,qtz,glau,bfn cly 2 38 9747.95 0.00 9.2 26.6 26.6 66.7 0.0 0.0 3.33 0.000 31.600 ND SS- vwcmt,qtz,glau,sid 2 39 9749.05 1.17 16.0 21.5 19.7 68.7 1.8 0.0 2.80 0.000 31.600 0.142 SS-wcrnt,qtz,glau,occ wh cht 2 40 9750.00 0.12 11.5 29.4 28.0 62.9 1.4 0.0 2.81 0.000 31.600 0.091 SS-vwcmt,qtz,glau,brn cly,occ wh cht 2 41 9751.10 0.00 4.4 63.8 58.8 34.4 5,0 0.0 3.47 0.000 31.600 0.096 SS-vwcrnt,qtz,gbu,sid,occ cht phi 2 42 9752.15 0.14 8.7 16.1 14.3 70.9 1.9 0.0 2.76 0.000 31.600 0.087 SS-vwcmt,qtz,glau,brn cly,wh cbt 2 43 9753.05 0.08 10.2 24.5 22.4 68.0 2.1 0.0 2.75 0.000 31.600 0.141 SS-vwcmt,qtz,glau,brn cly,wh cht 2 44 9754.05 0.00 2.4 94.3 75.2 21.0 19.0 0.0 3.58 0.000 31.600 0.184 SS-vwcrnt,qtz,sid,occ gLau,vug 2 45 9755.00 Broken 10.1 22.1 19,1 69.8 3.0 0.0 2.76 0.000 31.600 0.130 SS-vwcmt,qtz,glau,brn cly,occ wh cht, brcken 2 46 9755.95 0.69 12.9 17.1 17.1 77.4 0.0 0.0 2.78 0.000 31.600 ND SS-wcmt, qtz,¢au,occ wh cht 2 47 9757.95 0.09 9.8 29.8 27.9 62.0 2.0 0.0 2.80 0.000 31.600 0.114 SS-wcmt,qtz,glau,brn cly,occ wh cht 2 48 9758.95 0.00 3.1 68.7 68.7 25.9 0.0 0.0 3.45 0.000 31.600 ND SS- vwcmt,qtz,sid,occ glau 2 49 9760.05 0.65 12.7 34.7 33.1 53.3 1.6 0.0 2.75 0.000 31.600 0.082 SS-wcmt, qtz,glau,occ wh cht 2 50 9761.05 0.07 8.2 20.0 18.2 73.2 1.8 0.0 2.78 0.000 31.600 0.133 SS-wcrnt,qtz,glau,brn cly,occ wh cbt 2 51 9762.20 0.24 8.1 30.3 27.9 66.1 2.4 0.0 3.09 0.000 31.600 0.097 SS-vwcmt,qtz,glau,sid,occ brn cly,fac 2 52 9763.05 0.20 9.3 22.4 22.4 75.5 0.0 0.0 2.84 0.000 31.600 ND SS-wcmt,qtz,glau,brn cly,occ wh cht 3 1 9764.20 0.01 8.2 25.3 25.3 71.0 0.0 0.0 3.36 0.000 30.550 ND SS-vwcmt,qtz,glau,sid, ccc a-g ¢ 3 2 9765.05 0.07 10.3 25.5 25.5 64.1 0.0 0.0 3.05 0.000 30.550 ND SS-vwcmt,qtz,glau,sid, ccc arg gr 3 3 9766.05 6.58 17.6 31.2 25.9 56.2 5.3 0.0 2.79 0.000 30.550 0.481 SS-wcmt,qtz,glau,occ wh cmt 3 4 9767.25 0.95 17.4 29.8 27.1 56.5 2.8 0.0 3.09 0.000 30.550 0.196 SS-wcmt,qtz,glau,pchsid,w~h crnt,rr lith pb~ 3 5 9768.05 3.71 17.6 31.6 25.8 51.0 5.8 0.0 2.95 0.000 30.550 0.490 SS-wcmt,qtz,glau,pch sid,w~h cmt,rr lith phi *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFERTO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE' BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS . . DEAN STARK ANALYSIS PERMEAB LITY POROSITY SATURATIONS GRAIN MUD # # FT MD (%) %Pr~ %Pr ~ % Pv 1%Pr ~ %Pr GM/CC PPM PPM % DESCRIPTION ,,, 3 6 9769.05 0.17 10.3 25.8 23.8 67.5 2.0 0.0 3.07 0.000 30.550 0.101 SS-vwcmt,qtz,glau,sid 3 7 9770.20 2.75 16.7 25.1 21.2 58.7 3.9 0.0 2.94 0.000 30.550 0.311 SS-wcmt, qtz,gtau,brn cly,occ wh cbt 3 8 9771.05 0.52 15.6 23.8 22.0 61.8 1.8 0.0 3,02 0,000 30.550 0.116 SS-wcmt, qtz,glau,br n cly,occ Ifth pbl 3 9 9772.05 0.89 16.4 16.8 15.4 89.0 1.4 0.0 3.19 0.000 30.550 0.111 SS- wcmt,qtz,glau,sid,lith pM 3 10 9773.15 0.27 14.0 21.0 19.8 73.6 1.2 0.0 3.04 0.000 30.550 0.083 SS-wcmt,qtz,gtau,sid,lith 3 11 9774.25 0.53 15.2 18.7 17.3 72.9 1.4 0.0 3.04 0.000 30.550 0.094 SS- vwcmt,cCz, glau,sid 3 12 9775.05 0.07 12.8 17.6 17.6 78.5 0.0 0.0 3.12 0.000 30.550 ND SS- vwcmt,qtz, glau,sid,occ lith phi ~sml rugs 3 13 9776.15 0.14 11.9 13.2 13.2 88.7 0.0 0.0 3.19 0.000 30.550 ND SS-vwcmt,qtz,brn lith gr,occ glau,sid,sml vugs 3 14 9777.05 0,17 12.7 16.6 16.6 85.7 0.0 0.0 3.19 0.000 30.550 ND SS-vwcmt,qtz,brn arg gr,sid 3 15 9778.05 0.20 16.6 8.5 7.9 88.2 0.6 0.0 3.24 0.000 30.550 0.072 Cgl-vwcmt,brn lith pb{,qtz,occ glau,lim 3 16 9779.05 0.13 16.0 -3.5 -3.5 97.3 0.0 0.0 3.23 0.000 30.550 ND CgI-vwcmt,brn lith pl~,qtz,occ glau,lim 3 17 9780.05 0.13 15.5 9.6 9.6 87.1 0.0 0.0 3.20 0.000 30.550 ND SS- vwcmt,qtz,glau,lith pbl,occ 3 18 9781.05 0.06 16.1 12.9 12.9 85.3 0.0 0.0 3.18 0.000 30.550 ND SS- vwcmt,qtz,glau,lith pbl,occ lim 3 19 9782.00 0.29 15.3 10.8 10.8 87.8 0.0 0.0 3.14 0.000 30.550 N D SS-vwcmt,qtz, glau,sid 3 20 9783.05 0.18 15.1 20.4 20.4 86.6 0.0 0.0 3.16 0.000 30.550 ND SS-wcmt,qtz,brn arg gr,lr lira 3 21 9784.05 0.08 14.7 11.2 11.2 86.1 0.0 0.0 3.14 0.000 30.550 ND SS-wcmt,qtz,glau,brn arg 9r ,t lim 3 22 9785.25 0.26 15.3 6.0 6,0 92.3 0.0 0.0 3.11 0.000 30.550 ND SS-vwcmt,qtz,glau,brn arg gr 3 23 9786.05 0.22 15.4 12.8 12.8 88.5 0.0 0.0 3.15 0.000 30.550 ND SS- vwcmt,qtz,glau,br n arg 3 24 9787.05 0.17 12.7 20.0 20.0 81.0 0.0 0.0 3.23 0.000 30.550 ND SS-vwcmt,qtz,glau,brn arg gr,sid 3 25 9788.25 1.1 9 16.7 17.3 17.3 82.8 0.0 0.0 2.82 0.000 30.550 ND SS- wcmt, qtz, glau,lith phi 3 26 9789.05 6.66 19.5 22.1 20.7 73.0 1.4 0.0 2,84 0.000 30.550 0.148 SS- wcmt,qtz,glau,lith pbl,fr ac 3 27 * 9790.05 74.59 23.8 75.2 74.2 48.7 1.0 0.0 3.14 0.000 30.550 0.180 SS-wcmt,qtz,glau,lith pbl,frac 3 28 9790.95 41.63 15.0 23.4 21.4 71.1 2.0 0.0 3.19 0.000 30.550 0.128 SS-vwcmt,qtz,glau,sid,brn arg gr,frac 3 29 9791.95 Broken 17.4 9.2 8.1 82.4 1.1 0.0 3.24 0.000 30.550 0.098 SS-vwcmt,qtz,brn arg gr,lith pbl,sml rugs,broken 3 30 9793.05 112.13 21.4 34.1 31.5 60.7 2,6 0.0 2.81 0.000 30.550 0.271 SS-mod to vwcmt,qtz,glau,brn arg gr,sid *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA DEAN STARK ANALYSIS FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS PERMEAB UTY POROSITY SATURATIONS GRAJN MUD CORE SMPL DEPTH K,NR (HELIUM) OIL '1COR O1~ WATERI HEXAD.I FILTRA. DENSITY TRACER TRACER HEXAD.- ' # # FT . MD (%) %PrJ/''%Pv %Pv.1%Pv [ %Pv GM/CC PPM PPM % DESCRIPTION . . 3 31 9794.05 3.59 20.4 20.5 19.3 74.2 1.2 0.0 2.97 0.000 30.550 0.127 SS-vwcmt,qtz,glau,occ It brn arg gr 3 32 9795.05 12.94 22.9 45.2 43.8 46.8 1.4 0.0 3.16 0.0(X) 30,550 0.178 cgl-vwcmt, brn a"g ~7,qtz, glau,sid,vugs 3 33 9796.00 5.11 14.3 32.9 31.2 60.7 1.6 0.0 3.34 0.000 30.550 0.131 SS-vwcmt,qtz,glau,brn a-g gr,sid 3 34 9797.05 30.20 17.7 32.2 29.8 52.8 2.4 0.0 3.21 0.000 30.550 0,172 SS-vwcmt,qtz,brn arg gr,t glau,occ sml vugs 3 35 9798.05 44,55 23.5 25.4 23.1 58.4 2.2 0.0 3.11 0.000 30.550 0.246 SS-wcmt,qtz,gtau,sid 3 36 9799.20 233.11 24.5 46.0 31.7 37.1 14.3 0.0 3.22 0.000 30.550 1.383 SS- wcmt, qtz, gtau,sid 3 37 9800.05 9.29 20.7 36.3 29.8 53.0 6.5 0.0 3.37 0.000 30.550 0.660 SS-wcmt,qtz,gtau,sid,brn lith pbl,vugs 3 38 9801.05 8.96 15.0 27.7 24.1 62.6 3.6 0.0 3.19 0.000 30.550 0.276 SS-vwcmt,qtz,glau,brn arg gr,sid 3 39 * 9802.25 27.67 9.3 No Data 5.0 0.0 2.69 0.000 30.550 0.167 SS-pcmt, qtz,blk alt glau,b~n a/g (jr 3 40 * 9803.05 3.34 14.1 27.7 25.3 71.0 2.4 0.0 3.27 0.000 30.550 0.151 SS-wcmt,qtz,brn arg gr 3 41 9804.05 1.04 10.7 24.5 24.5 76.7 0.0 0.0 3.29 0.000 30.550 ND SS-vwcmt,qtz,brn arg gr,t glau 3 42 9805.00 18.50 18.6 46.0 35.9 43.5 10.1 0.0 3.39 0.0OO 30.550 0.812 SS-vwcmt,qtz,glau,it brn lith gr,wh cbt 3 43 9806.05 Broken 15.8 40.6 25.1 44.0 15.4 0.0 3.30 0.000 30.550 1.023 SS-vwcmt,qtz,glau,sid,bcken 3 44 9807.05 199.14 20.2 47.6 35.1 36.8 12.5 0.0 3.21 0.000 30.550 0.984 SS- wcmt,qtz,glau,sid,occ wh cmt 3 45 9808.20 253.53 22.9 57.2 30.9 33.0 26.3 0.0 3.03 0.000 30.550 2.372 SS-wcmt, qtz,glau,sid,occ wh cmt 3 46 9809.05 765.82 25.5 63.8 36.7 26.9 27.1 0.0 2.98 0.000 30.550 3.222 SS-wcmt, qtz,glau,sid,occ wh cmt 3 47 9810.05 278.59 22.8 56.8 31.8 32.8 25.0 0.0 3.12 0.000 30.550 2.234 SS-wcmt,qtz,glau,sid,occ wh crnt,sml frac 3 48 9811.20 739.56 26.0 59.9 37.0 27.7 22.9 0.0 3.02 0.000 30.550 2.290 SS-wcmt,qtz,glau,sid,wh cmt 3 49 9812.05 351.00 25.7 54.1 34.6 34.9 19.5 0.0 3.08 0.000 30.550 2.237 SS-wcmt,qtz,glau,sid,occ wh cmt 3 50 9813.05 Broken 31.2 No Data 25.1 28.8 0.0 2.94 0.000 30.550 3.097 SS-pcmt, qtz,glau,occ wh crnt, broken 3 51 9814.25 263.05 21.3 52.2 41.2 40.1 11.0 0.0 3.05 0.000 30.550 0.952 SS-mod to wcmt, qtz,glau,sid,l' wh cmt,frac 3 52 9815.05 6.53 13.7 35.2 27.1 58.4 5.7 2.4 3.37 0.050 30.550 0.372 SS- vwcmt,qtz, glau,sid,frac 3 53 9816.05 409.96 29,0 51.5 38.5 42.2 13.0 0.0 2.87 0.000 30.550 1.505 SS-mod cmt,qtz,glau,tr wh cmt 3 54 9817.15 461.02 26.0 46.7 38.4 36.3 10.3 0.0 2.95 0.000 30.550 1.1 69 SS-wcmt,qtz, glau,sid,tr wh crnt 3 55 9818.05 104.58 21.9 44.2 31.9 44.9 12.3 0.0 3.14 0.000 30.550 1.104 SS-wcmt,qtz,gtau,brn arg gr,sid .... *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA CORE LABORATORIES FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERMEABI UTY POROSITY SATURATIONS G P,,N N MUD' "' ~. ~ ~ MD (%) % ~ % ~ [ % ~ I . % ~ 1% ~ GM/CC P~M PPM . .. % DESCRI~ION 3 ~ ~19.05 ~.84 ~.6 ~.5 47.1 44.9 13.4 0.0 3.~ 0.~ ~.5~ 1.323 SS- mod cmt,q~,gbu,~ n c~ 3 57 ~.25 1~.19 ~.9 No ~ 44.8 7.6 0.0 3.03 0.~ ~.5~ 0.~3 SS-p to wcmt,~,gbu,t wh cmt 3 ~ ~21,05 170.21 23.6 67.1 57.9 44.3 9.2 0.0 3.12 0.~ ~.5~ 0.~1 SS-mod to wcmtq~,¢u,~ac 3 59 ~.~ 1 ~.95 ~.9 40.3 ~.7 41.7 4.5 0.0 3.~ 0.~ ~.550 0.473 SS-wcmt,~,~u,sid,brn ~g ~ 4 1 ~23.05 ~.49 17.4 37.1 ~.0 47.7 3.0 0.0 3.14 0.~ ~.5~ 0.~8 SS- ~cmt,q~, gbu,sid 4 2 9~4.05 B~en 18.9 31.1 27.6 47.0 3.5 0.0 3.12 0.~ ~.5~ 0.277 SS-~mt,q~,gbu,sid,b~en 4 3 ~25.05 9.25 13.4 45.0 42.2 ~.3 2.8 0.0 3.~ 0,~ ~.~ 0,1~ SS-~cmt,q~,gbu,sid 4 4 * ~25.95 B~en 18.0 53.7 52.6 45.3 1.1 0.0 3.~ 0.~ ~.5~ 0.~1 SS-wcmt,¢,¢u,bn cly,b~en 4 5 ~7.05 27.~ 23.1 ~.0 ~.8 59.1 3.2 0.0 2.97 0.~ ~.5~ 0.~4 SS-wcmt,~,¢u,bn arg ~ 4 6 ~8.~ 5.69 15.7 28.1 25.1 ~.6 2.9 0.0 3.~ 0.~ ~.5~ 0.175 SS-w to ~mt,q~,gbu,sid,b n c~ 4 7 ~.10 1~.49 ~.1 37,5 32.9 42.7 4.5 0.0 3.~ 0.~ ~.5~ 0.372 SS-p to ~cmt,q~,gbu,sid,bn c~,ffac 4 8 * 9~.05 1~.~ 19.2 73.3 73.3 34.2 0.0 0.0 3.15 0.~ ~.~ ND SS-wcmt,~,~nag ~,f~c 4 9 ~1.05 1.11 18.3 28.7 28.7 65.6 0.0 0.0 3.~ 0.~ ~.5~ ND SS-~cmt,q~,gbu,sid,~n arg gr,rr p~ & rug 4 10 ~2.25 ~.15 18.1 ~.4 ~.1 ~.6 1.2 0.0 3.~ 0.~ ~.5~ 0.1 ~ SS-~cmt,q~,gbu,sid,b n cly,~ac 4 11 ~.05 ~.72 18.5 39.7 ~.4 ~.8 4.3 0.0 3.~ 0.~ ~.5~ 0.~2 SS-~cmt,q~,gbu,sid,~n cly 4 12 ~.05 ~.97 ~.2 42.8 ~.0 42.8 2.8 0.0 2.~ 0.~ ~.~ 0.279 SS-wcmt,~,¢u,~c sid,~ ~ate 4 13 ~.~ 8.76 14.4 28.6 27.1 ~.1 1.5 0.0 3.03 0.~ ~.~ 0.119 SS- ~cmt,q~,gbu,sid,~n cly 4 14 ~.05 23.28 17.6 32.7 ~.8 ~.2 1.9 0.0 3.01 0.~ ~.5~ 0.145 SS-~cmt,q~,gbu,sid,bn c~ 4 15 ~7.05 1 ~.~ ~.8 42.8 41.3 51.8 1.4 0.0 3.~ 0.~ ~.5~ 0.131 SS-wcmt,~,¢u,~n cly,~gs 4 16 ~.~ 43.52 ~.1 36.9 ~.9 49.1 3.0 0.0 3.10 0.~ ~.5~ 0.~3 SS-wcmt,~,¢u,~n cly,~ wh cht,s~ 4 17 ~9.05 23.67 17.7 ~.9 31.8 55.2 3.0 0.0 3.16 0.~ ~.5~ 0.230 SS- ~cmt,q~,gbu,sid,bn cly 4 18 ~0.05 39.~ 18.7 41.0 32.2 45.4 8.8 0.0 3.17 0.~ ~.5~ 0.634 SS-~cmt,q~,gbu,sid,~n cly 4 19 ~1.05 161 .~ ~.4 41.6 ~.2 43.5 5.4 0.0 3.03 0.~ ~.5~ 0.4~ SS-w to ~mt,~,g~u,sid,~ac 4 ~ ~2.05 418.~ 18.8 46.3 ~.0 42.9 16.4 0.0 3.~ 0.~ ~.5~ 1.1 82 SS-w to ~mt,q~,g~u,sid,~ac 4 21 9~3.05 1~.28 ~.1 62.4 37.1 28.1 25.3 .. 0.0 2.~ 0.~ ~.5~ 2.827 SS-wcmt,~,¢au,t wh cbt *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA CORE SMPL # # DEPTH FT I PERM EABI LITY I I KAIR MD (HELIUM) 20.7 29.7 28.1 CORE LABORATORIES DEAN STARK ANALYSIS , SATURATIONS , OiL I COROiLI WATERI HEXAD, I FILTRA. %~ l, ,%~vl %Pvl,%~vl %~v DENSITY GM/CC 3.01 MUD TRACER TRACER HEXAD. PPM PPM % 4 22 9844.05 405.85 55.5 36.2 40.2 19.3 0.0 0.000 30.550 1.550 4 23 9845.05 1309.35 62.2 33.7 30.3 28.6 0.0 2.81 0.000 30.550 3.510 4 24 9846.05 1154.10 57.5 30.1 32.1 27.4 0.0 2.90 0.000 30.550 2.944 4 25 9847.25 No Sample 4 26 9848.05 626.74 27.4 55.2 37.9 36.0 17.4 0.0 2.89 0.000 30.550 1.832 4 27 9849.05 1121.32 26.2 52.5 -8.5 37.0 61.0 0.0 2.94 0.000 30.550 7.633 4 28 9850.25 991.27 25.4 54.7 30,1 34.5 24.6 0.0 2,95 0.000 30.550 2.443 4 29 9851.05 606.33 24.2 54.4 47.0 36,1 7.4 0.0 2.95 0,000 30.550 0.823 4 30 9852.25 652.38 25.6 55.6 32.4 33.6 23.2 0.0 2.92 0.000 30,550 2.422 4 31 9853.05 519.96 23.2 57.3 31.3 35.8 26.0 0.0 2.93 0.000 30.550 2.209 4 32 9854.05 585.17 24.9 56.3 31.4 35.9 24.9 0.0 2.97 0,000 30.550 2.364 4 33 9855.00 512.19 23.9 54.0 26.7 40.1 27.3 0.0 2.88 0.000 30.550 2,454 4 34 9856.05 652.38 26.4 55.8 31.4 33.5 24.4 0.0 2.87 0.000 30.550 2.703 4 35 9857.05 222.75 25.5 49.5 28.7 39,1 20.8 0.0 2.89 0.000 30.550 2.038 4 36 9858.15 217.09 24.0 52.4 35.3 41.1 17.1 0.0 2.94 0.000 30.550 1.547 4 37 9859.05 117.09 21.4 48.1 31.5 42.7 14.5 0.0 3.17 0.000 30.550 1.468 4 38 9860.05 6.37 19.4 39.9 36.2 55.3 3.7 0.0 3.38 0.000 30.550 0.3.34 4 39 9861.20 21.42 18.5 49.8 45.4 37.4 4.4 0.0 3.22 0.000 30.550 0.487 4 40 9862.05 97.66 18.8 49.2 34.6 41.2 14.6 0.0 3.03 0.000 30.550 1.152 4 41 9863.05 85.08 19.0 34.9 26.9 35.2 8.0 0.0 3.00 0.000 30.550 0.622 4 42 * 9864.25 35.45 18.7 69.6 64.3 43,1 5.2 0.0 3.28 0.000 30.550 0.465 4 43 * 986505 3.13 18.7 25.9 24.7 72.7 1.2 0,0 3,28 0.000 30.550 0.088 4 44 9866.05 7.23 17.9 39.4 37.7 52.4 1.7 0.0 3.20 0.000 30.550 O. 130 4 45 9867.25 238.03 24.0 55.2 33.0 33.4 22.2 0.0 2.98 0,000 30.550 2.255 4 46 9868.00 29.71 20.1 45.8 38.4 43.5 7.4 0.0 3.16 0.000 30.550 0.669 FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DESCRIPTION SS-vwcmt,qtz,glau,sid,occ wh cht SS-wcmt,qtz,glau,ff wh cht SS-wcmt,cltz,glau,ff wh cbt SS-wcmt,qtz,glau,occ wh cht SS-wcmt, qtz,glau,ff wh cht SS-wcmt, qtz,glau,occ wh cbt SS-wcmt,qtz,glau,occ wh & brn cly SS-wcmt,qtz,glau,occ wh cht SS-wcmt,qtz,glau,occ wh cht SS-wcmt,qtz,glau,occ wh cht SS-wcmt,qtz,glau,wh cht SS-wcmt,qtz,gtau,wh cht~r lith SS-wcmt,qtz,¢au,occ wh ct SS-wcmt, qtz,brn a-g gr, occ glau & wh cht SS-wcmt,qtz,brn a-g gr,glau,sid,occ wh cht SS-wcmt, qtz,l:rn ~g 9r,glau,sid,t hem SS-wcmt,qtz,brn arg gr,glau,sid,t hem SS-vwcmt,qtz,glau,sid,occ wh cht SS-wcmt,q~,gtau,sid~r a'g pb~ SS-wcmt,qtz,lith g'- pbt,glau,brok en SS- wcmt,qtz,lith gr- pbl,glau,vugs SS-vwcmt,qtz,d< brn a-g ~r,sid.tr glau,vugs SS-wcmt,qtz,glau,occ wh cmt SS-wcmt,qtz,gtau,brn cly,sid *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS ARCO ALASKA, INC. P1-20 Pt. MctNTYRE UNIT NORTH SLOPE, ALASKA CORE LABORATORIES FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERMF__.AEILITY POROSITY SATURATIONS GRAIN MuD ' # # , FT MD. (%.) % Pr..I'% Pr..[ % Pv 1% Pv J %Pr GM/CC PPM , .pPM % DESCRIPTION .... 4 47 9869.05 11.52 18.1 38.7 36.1 52.2 2.6 0.0 3.25 0.000 30.550 0.198 SS-wcmt, cltz,glau,b~n cly,sid 4 48 9870.05 93.30 18.9 49.4 29.8 33.0 19.6 0.0 3.12 0.000 30,550 1.546 SS-vwcmt,qtz,glau,sid,ooc wh cmt 4 49 9871.05 212.43 20.5 60.9 29.1 25.8 31 o8 0.0 3.01 0.000 30.550 2.992 SS-wcmt,qtz,glau,sid,occ wh cmt 4 50 9872.05 12.13 18.4 39.6 32.6 37.6 7.0 0.0 3.26 0.000 30.550 0.548 SS-wcmt, qtz, glau,sid,occ wh cmt 4 51 9873.25 55.31 19.5 47.4 32.6 35.5 14.8 0.0 3.15 0.000 30.550 1.110 SS- wcmt, qtz, glau,sid,occ wh cmt 4 52 9874.05 17.22 18.0 52.9 29.1 37.4 23.8 0,0 3.25 0.000 30.550 1.61 6 SS-wcmt,qtz,glau,sid,occ wh cmt 4 53 9875.05 30.09 17.5 42.9 28.0 42.2 14.9 0.0 3.26 0.000 30.550 1.260 SS-wcmt, qtz,glau,sid,o¢,c wh cmt 4 54 9876.25 73,07 17.8 47.4 29.5 35.1 17.9 0.0 3.13 0.000 30.550 1.240 SS-wcmt,qtz,glau,sid,occ wh cmt 4 55 9877.05 10.34 15.3 35.3 30.8 44.9 4°6 0.0 3.11 0.000 30.550 0.334 SS-wcmt,qtz,glau,sid,occ wh crnt 4 58 9878.05 81.81 17.9 45.5 33.5 42.0 11.9 0.0 3.10 0.000 30.550 0.823 SS-wcmt,qtz,glau,sid,occ wh cmt 4 57 9879.05 63.55 19.5 48.3 28.8 40.9 15.1 4.5 2.98 0.115 30.550 1.1 95 SS-wcmt, qtz,glau,sid,occ wh cmt 4 58 9880.05 26.54 10.1 29.1 21.8 61.5 7.3 0.0 3.21 0.000 30.550 0.315 SS-vwcmt,qtz,glau,wh cmt 4 59 9881.05 254.17 19.5 54.3 29.4 35.2 22.4 2.4 3.10 0.060 30.550 1.751 SS- vwcmt,qtz,glau,wh cmt 4 60 9882.05 350.64 22.6 56.8 32.7 34.0 22.5 1.6 3.03 0.051 30.550 2.201 SS-mod cmt,qtz,glau,wh cmt 5 I 9883.05 345.42 19.8 56.8 25.2 31.1 25.0 6.5 3.07 0.165 30.400 1.990 SS-mod to wcmtqtz,wh cht,glau,sid 5 2 9884.05 207.23 24.5 54.3 35.7 33.3 18.6 0.0 3.05 0.000 30.400 1.849 SS-mod to wcmtqtz,glau,occ wh cht 5 3 9885.00 282.68 23.9 50.0 38.5 30.4 19.6 1.9 2.94 0.076 30.400 2.443 SS- modcmt,qtz,glau,wh cmt 5 4 9886.05 12.35 11.5 38.3 21.4 45.5 13.7 3.2 3.20 0.054 30.400 0.721 SS-vwcmt,qtz,occ gbu,wh cmt 5 5 9886.90 43.58 16.9 52.0 33.0 34.8 12.9 6.2 3.11 0.128 30.400 0.832 SS-mod to wcmf, qtz,occ glau,sid,ooc wh cht 5 6 9888.05 258.46 23.7 59.7 39.5 27.5 18.8 1.3 2.85 0.053 30.400 2.343 SS-modcmt,qtz,occ glau & wh cht 5 7 9889.05 72.62 18.6 53.8 28.0 30.4 13.9 11.9 3.04 0.318 30.400 1.152 SS-mod to vwcmt,qtz,sid,wh cmt,~* glau 5 8 9890.05 568.15 22.4 67.5 31.0 19.7 22.2 14.4 3.11 0.407 30.400 1.951 SS-mod to vwcmt, qtz,sid,wh cmt,t glau 5 9 9891.05 384.35 22.7 70.6 41.1 18.0 25.8 3.8 3.01 0.132 30.400 2.781 SS-mod to wcmtqtz,wh cht~r ck lith ¢ 5 10 9892.05 463.75 23.7 69.3 44.9 18.2 18.7 5.7 3.02 0.181 30.400 1.862 SS- mod cmt,qtz,wh cht,t sid 5 11 9893.05 774.31 27.0 70.9 44.8 18.5 22.1 3.9 2.97 0.126 30.400 2.247 SS-mod cmt,qtz,wh cbt ~ & cmt, occ sid - . ........ , *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MclNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERMEABIUTY~ POROSITY SATURATIONS GR,NN MUD ld 1 r il..... # # FT M.D .... (%) % Pv % Pv ! % Pv 1% Pv [ % Pv GM/CC. PPM PPM % DESCRIPTION 5 12 9894.25 1713.32 26.3 72.7 31.2 15.4 31.5 9.9 2.93 0.191 30.400 1.898 SS- mod to vwcrnt, qtz,wh cbt gr,occ sid 5 13 9895.00 479.28 23.8 63.3 36.7 21.3 14.4 12.1 2.96 0.413 30.400 1.524 SS-mod to wcmtqtz,wh cht~r CE lith gr,sid 5 14 9895.90 0.01 5.9 24.2 18.7 58.7 5.5 0.0 3.26 0.000 30,400 0.202 SS-vwcmt,qtz,wh cht,sid,t glau 5 15 9897.05 361.71 23.2 65.3 33.6 19.5 19.7 11.9 2.95 0.358 30.400 1.844 SS-wcmt, qtz,wh chtocc sid,t glau 5 16 9898.05 376.93 26.4 69.7 47.1 24.6 19.5 3.1 2.91 0.102 30.400 1.997 SS-wcmt, qtz,wh cht, occ sid,t cE lith Gr 5 17 9899.05 0.05 4.0 46.8 34.1 48.5 12.7 0.0 3.32 0.000 30.400 0.238 SS-vwcmt,qtz,sid,occ wh cbt 5 18 9900.05 61.02 19.3 60.3 32.9 26.1 14.4 13.0 3.17 0.364 30.400 1.255 SS-w to vwcmt, qtz,sid,occ wh cht 5 19 9901.05 556.17 25.7 72.2 29.7 18.0 24.6 17.9 2.99 0.710 30.400 3.030 SS-mod cmt,qtz,wh cht,occ cE lith (jr 5 20 9902.05 2.06 6.6 27.8 13.6 44.5 14.3 0.0 3.13 0.000 30.400 0.500 SS-vwcmt,qtz,sid,wh cht, tr glau,broken 5 21 9<-:-:-:-:JO3.25 0.28 7.8 18.2 8.6 47.2 9.5 0.0 3.13 0.000 30.400 0.393 SS-vwcmt,qtz,sid,wh cht, t glau 5 22 9904.05 763.60 26.5 77.7 27.5 16.1 30.3 19.9 2.77 0.622 30.400 2.952 SS-wcmt,qtz,wh chLrr cE lith (jr 5 23 9905.05 1344.14 28.1 80.7 30.3 11.5 39,1 11.4 2.73 0.394 30.400 4.227 SS-wcmt, qtz,wh chLrr cE lith gr 5 24 9906.15 280.81 15,9 68.9 43.4 18.7 15.4 10.1 2.97 0.173 30.400 0.818 SS-w-vwcmt, qtz,wh cht, sid,occ glau,ffac 5 25 9907.15 132.37 25.7 69.8 43.2 18.6 8.6 18.0 2.70 0.760 30.400 1.125 SS-wcmt,qtz,wh chUr cE lith gr 5 26 9908.05 1668.20 29.0 79.3 29.0 12.4 32.4 17.9 2.68 0.782 30.400 4.423 SS-mod to wcmt, ql:z,wh cht~r CE lith gr 5 27 9909.20 1397.70 28.2 78.2 30.3 12.7 32.6 15.3 2.72 0.540 30.400 3.603 SS-mod to wcmt, qtz,wh chtJT cE lith gr 5 28 9910.O0 1452.32 28.2 73.1 30.0 19.6 38.3 4.8 2.68 0.202 30.400 5.031 SS- mod to wcmt, qtz,wh chtj-r cE lith gr 5 29 9911.05 853.31 27.6 74.5 44.5 14.9 21.3 8.7 2.69 0.315 30.400 2.408 SS-mod to wcmt, qtz,vCn cht~r ck lith g' 5 30 9912.00 1582.47 29.5 77.7 44.1 14.5 30.4 3.2 2.68 0.126 30.400 3.743 SS-mod to wcmt, qtz,wh chUr ck lith ¢r 5 31 9913.25 509.50 19.1 66.5 40.6 17.0 22.4 3.6 2.95 0.091 30.400 1.759 SS-w to wvcmt, qtz,wh cht,rr cE lith Gr 5 32 991 4.05 1048.98 26.7 76.5 31.2 14.0 35.3 10.0 2.69 0.358 30.400 3.91 8 SS- mod to wcmt, qtz,wh chtj'r cA lith gr i 5 33 991 5.05 11 4.45 1 5.7 32.9 8.5 23.3 21.1 3.2 3.02 0.069 30.400 1.390 SS-vwcmt,qtz,wh cht,sid,occ ck¢ ,stol frac 5 34 9916.25 1569.41 28.8 84.9 43.2 10.5 41.8 0.0 2.68 0.000 30.400 5.438 SS- wcmt,qtz,wh cht, t~ glau 5 35 9918.05 624.09 22.8 71.4 44.2 16.7 24.9 2.3 2.83 0.073 30.400 2.463 SS-w to vwcmt,qtz,wh cht, occ cc/c¥ lam ~ 5 36 9919.25 2387.54 28.8 88.0 53.5 12.4 34.5 0.0 2.68 0.000 30.400 3.762 SS-mod to wcmt, qtz,wf~ cht,rr cE lith gr ~,. *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFERTO TEXT FOR DETAILS ARCO ALASKA, INC. P1-20 Pt. MclNTYRE UNIT NORTH SLOPE, ALASKA CORE LABORATORIES FILE' BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERM EAEI UTY POROSITY SATURATIONS GRAIN [ MUD # # FT MD (%) % PvI1~!% Pv % Pv I % Pv I. % Pv GM/CC PPM PPM % DESCRIPTION 5 37 9920.05 993.32 28.1 79.9 45.1 11.4 34.8 0.0 2.69 0.000 30.400 3.833 SS-wcmt,qtz,wh chUr ck lith gr 5 38 9921.05 0.11 7.9 29.2 22.2 40.7 7.0 0.0 3.15 0.000 30.400 0.236 SS- vwcmt,qtz,wh cht,sid,rr cf< lith gr 5 39 9922.00 7.67 8.1 28.8 16.3 35.0 12.4 0.0 3.11 0.000 30.400 0.405 SS-vwcmt,qtz,wh cht,sid,rr (~ lith gr 5 40 9923.05 1191.73 28.2 81.2 47.6 15.1 33.6 0.0 2.69 0.000 30.400 3.697 SS-wcmt, qtz,wh chtj'r ck lith gr 5 41 9924.05 1444.71 28.1 76.9 45.4 12.4 28.1 3.4 2.69 0.1 22 30.400 3.147 SS- wcmt, qtz,wh cbt 5 42 9925.15 513.25 24.6 68.0 48.7 17.3 19.3 0.0 2.71 0.000 30.400 1.772 SS-w to vwcmt,qlz,wh cht 5 43 9926.05 337.34 19.8 75.6 47.9 13.7 24.6 3.1 2.92 0.105 30.400 2.616 SS-w to v~cmt, qlz,wh cht, occ glau 5 44 9928.25 334.00 22.8 71.1 46.6 18.4 24.5 0.0 2.74 0.000 30.400 2.392 SS-w to w, cmt, qtz,wh cht 5 45 9929.05 0.11 11.6 46.5 39.4 33.7 7.1 0.0 3.09 0.000 30.400 0.366 SS-vwcrnt,qtz,wh cht,occ glau,sid 5 46 9930.25 1.77 13.4 34.2 27.2 52.8 7.0 0.0 2.75 0.000 30.400 0.498 SS-vwcrnt,qtz,wh cht, ck cly lam,glau 5 47 9931.20 390.87 25.1 62.1 42.3 29.7 19.8 0.0 2.74 0.000 30.400 2.026 SS-wcmt,qtz,wh chtglau 5 46 9932.05 90.85 21.5 59.5 30.8 28.6 28.7 0.0 2.75 0.000 30.400 2.511 SS-vwcmt,qtz,wh cht,occ d< lith gr & glau 5 49 9933.05 36.81 21.4 55.0 37.6 33.3 17,4 0.0 3.16 0.000 30.400 1.51 2 SS- wcmt,qtz,gtau,sid,occ wh cbt & rugs 5 50 9934.25 6.57 23.2 34.7 28.6 49.0 6.1 0.0 3.42 0.000 30.400 0.551 SS- vwcrnt,qtz,wh cht,sid,glau,sml vugs 5 51 9935.25 2.05 13.1 30.5 14.7 60.0 12.3 3.5 3.03 0.065 30.400 0.706 SS-vwcmt,qtz,wh cht,sid,glau 5 52 9936.05 54.81 20.1 46.2 27.4 38.8 16.9 1.9 3.00 0.047 30.400 1.329 SS-vwcmt,qtz,wh cht,sid,glau 5 53 9937.05 58.35 19.5 50.4 27.4 38.8 22.9 0.0 3.16 0.000 30.400 2.337 SS-wcmt, qtz,wh cht, sid,glau 5 54 9938.05 112.40 21.7 55.7 31.1 33.5 24.6 0.0 2.86 0.000 30.400 2.352 SS-wcmt,qtz,wh chtsid,glau 5 55 9939.25 98.40 21.6 50.6 25.5 41.2 25.0 0.0 3.12 0.000 30.400 2.668 SS-w to vw cmt,qtz,glau,sid,wh cht 5 56 9940.05 41.03 20.4 40.1 27.6 45.1 12.5 0.0 2.98 0.000 30.400 1.322 SS-w to vw cmt,qtz,glau,sid,wh cht ! 6 1 9941.1 5 76.05 21.5 45.2 19.1 41.6 15.0 11.1 3.01 0.327 30.550 1.372 SS- wcmt,qtz,gtau,sid,occ wh cmt 6 2 9942.05 95.10 21.4 50.6 22.9 38.2 25.0 2.8 3.05 0.113 30.550 3.165 SS- wcrnt,qtz,glau,sid,occ wh cmt 6 3 9943.05 206.24 23.1 58.0 34.4 36.0 21.6 0.0 2.97 0.000 30.550 1.899 SS-wcmt, qtz,glau,sid,occ wh cmt 6 4 9944.25 411.67 25.5 56.5 32.4 34.5 24.1 0.0 2.91 0.000 30.550 2.373 SS-wcmt,qtz,glau,wh cbt 6 5 9944.85 603.57 26.2 62.0 34.8 29.3 27.2 0.0 2.84 0.000 30,550 2.682 SS-wcrnt,qtz,glau,wh cbt -DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERM EAB LITY POROSITY SATURATIONS GR.NN MUD # # FI' MD (%) % PvI I% Pv [ . % Pv % Pv 1% Pv., . GM/CC PPM PPM % DESCRIPTION ....... 6 6 9946.05 678.04 26.9 58.4 44.8 29.6 13.6 0.0 2.86 0.000 30.550 1.424 SS-wcmt,qtz,glau,wh cht 6 7 9947.25 Broken 27.8 71.1 43.3 26.2 21.6 6.2 2.83 0.113 30.550 1.209 SS-wcmt,qtz,glau,wh cht, qtz & sid filled jr, broken 6 8 9948.05 835.24 27.7 57.9 41.8 25.6 16.2 0.0 2.80 0.000 30.550 1.924 SS-wcmt, qtz,glau,wh cbt 6 9 9949.05 313.94 23.2 49.8 37.1 31.3 12.7 0.0 2.86 0.000 30.550 1.307 SS-wcmt, qtz,glau,wh cht 6 10 9950.15 9.08 17.1 30.0 22.0 61.0 8.0 0.0 3.17 0.000 30.550 0.586 SS- vwcmt,qtz,glau,wh cht, occ brn cly 6 11 9951.05 20.27 19.9 34.1 25.3 53.7 8.8 0.0 2.96 0.000 30.550 0.831 SS-vwcrnt,qlz,glau,wh chtocc brn cly 6 12 9952.05 27.87 19.9 32.2 22.9 52.5 9.3 0.0 2.98 0.000 30.550 0.766 SS-vwcmt,qtz,ck bm cly, occ sid 6 13 9953.25 26.75 17.0 46.9 42.1 52.3 4.8 0.0 3.12 0.000 30.550 0.347 SS-vwcmt,qtz,sid,glau,occ rugs 6 14 * 9954.05 49.88 17.5 70.8 64.4 24.1 6.4 0.0 3.21 0.000 30.550 0.448 SS-vwcmt,qtz,sid,brn ~g gr,occ vugs,frac 6 15 9954.95 39.66 21.2 64.9 62.1 40.5 2.9 0.0 3.22 0.000 30.550 0.279 SS-vwcrnt,qtz,sid,brn arg Gr,vugs 6 16 9956.25 Broken 19.6 88.1 83.2 47.0 4.9 0.0 2.95 0.000 30.550 0.474 SS-p towvcmt, qtz,bk vit cmt, occ glau,broken 6 17 9957.05 45.82 18.3 44.9 38.8 42.6 6.2 0.0 3.04 0.000 30.550 0.509 SS-vwcrnt,qtz,ck bm cly, smlvugs,brok en 6 18 9958.05 42.28 19.0 45.0 40.5 51.3 4.5 0.0 2.91 0.000 30.550 0.400 SS-vwcmt,qtz,glau,sid,occ whcht 6 19 9959.15 Broken 18.9 35.9 30.8 64.8 5.1 0.0 3.05 0.000 30.550 0.458 SS-p to vwcmt,qlz,glau,sid,occ wh cht,brcken 6 20 9960.05 182.04 22.9 15.5 6.9 38.1 8.6 0.0 2.84 0.000 30.550 0.957 SS-wcrnt,qtz,glau,occwh cht & bk cmt 6 21 9961.05 181.67 24.6 40.0 32.8 38.1 7.2 0.0 2.81 0.000 30.550 0.799 SS-wcmt, qtz,glau,occ wh cht& brn cly 6 22 9962.20 135.78 23.2 37.4 32.7 42.8 4.7 0.0 2.84 0.000 30.550 0.485 SS-wcmt,qtz,glau,occwh cht& bk cmt 6 23 9963.05 54.76 20.0 35.3 28.9 47.4 6.4 0.0 2.94 0.000 30.550 0.565 SS-wcmt,qtz,glau,occwh cht& bk cmt 6 24 9964.05 190.03 25.0 42.4 27.4 44.6 15.0 0.0 2.95 0.000 30.550 1.697 SS-wcrnt,qtz,glau,occ wh cbt & bk cmt 6 25 9965.15 247.18 25.0 45.7 24.8 42.6 20.8 0.0 2.94 0.000 30.550 2.316 SS-wcmt,qtz,cjiau,occ wh cbt & brn cly 6 26 9968.05 274.33 27.4 38.8 31.5 40.9 7.4 0.0 2.89 0.000 30.550 0.927 SS-wcmt,qtz,glau,occ wh cht & bk cmt 6 27 9967.05 122.89 23.8 38.6 32.7 48.2 5.8 0.0 2.98 0.000 30.550 0.567 SS-wcmt, qtz,gtau,occ wh cbt & bk cmt 6 28 9968.05 74.79 21.9 35.2 30.0 54.1 5.2 0.0 3.03 0.000 30550 0.497 SS-wcrnt, qtz,glau,occ wh cht & bk cmt 6 29 9969.05 Broken 22.0 52.5 47.9 51.1 4.5 0.0 3.04 0.000 30.550 0.487 SS-pcmt, qtz,glau,wh cht, bk crnt,broken 6 30 9970.25 52.97 20.8 29.7 19.2 58.4 10.4 0.0 2.97 0.000 30.550 0.938 SS-wcmt,qtz,glau,occ wh cmt *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIM E CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERMEABI UTY POROSITY SATURATIONS GRAIN MUD ......... # # .... FT MD (%) % PvI'% Pv J ..... %.PrJ % Pv 1% Pv GM/CC PPM PPM % DESCRIPTION I 6 31 9971.25 Broken 22.7 29.8 24.4 56.5 5.4 0.0 2.97 0.000 30.550 0.571 SS-pcmtqtz,glau,wh chtbk cmt, broken 6 32 9972.00 Broken 26.0 34.5 27.8 45.8 5.1 1.6 2.80 0,059 30.550 0.578 SS-pcmtqtz,glau,wh cht, bk crnt,broken 6 33 9973.05 15.59 19.0 27.9 20.9 59.7 7.1 0.0 2.92 0.000 30.550 0.561 SS-wcmt,qtz,glau,b~n cly lam 6 34 9974.05 0.55 14.2 13.4 9.9 80.0 3.5 0.0 3.04 0.000 30.550 0.216 SS-wcmt, qtz,glau,brn cly lam,sid 6 35 9975.20 31.67 20.2 35.6 31.4 54.8 4.2 0.0 2.93 0.000 30.550 0.373 SS-wcmt,qtz,glau,brn cly,sid,occ vugs 8 36 * 9976.05 0.28 25.8 10.4 9.3 91.1 1.2 0.0 3.42 0.000 30.550 0.148 SS-vwcmt,qtz,brn cly,sid,lim,occ glau,occ vugs 6 37 9977.05 0.85 24.2 10.7 8.6 92.8 2.1 0.0 3.52 0.000 30.550 0.238 Cgl-wcmt, lim,hem,qtz,occglau 6 38 9978.15 0.10 24.3 6.3 5.0 94.0 1.4 0.0 3.48 0.000 30.550 0.1 54 SS- wcmt,hem,lim,qtz, glau 6 39 9979.15 0.32 21.1 7.8 6.4 92.1 1.4 0.0 3.42 0.000 30.550 0.137 Cgl- wcmt,lim,hem,qt~,occ glau 6 40 9980.05 0.26 27.7 10.4 8.7 92.3 1.6 0.0 3.66 0.000 30.550 0.240 SS - wcmt, hern,lim,qtz, gla u 6 41 9981.05 0.23 24.6 12.4 10.6 91.2 1.8 0.0 3.53 0.000 30.550 0.315 SS- wcmt,hem,lim,qtz, glau 6 42 9982.05 0.34 25.4 9.8 8.3 93.2 1.5 0.0 3.52 0.000 30.550 0.192 SS- wcmt,hem,lim,qtz,glau 6 43 9983.05 0.15 19.2 14.6 13.4 87.1 1.2 0.0 3.18 0.000 30.550 0.103 SS- wcmt, lim,hem,qtz, glau 6 44 9984.05 8.57 27.3 15.4 9.9 88.5 3.6 1.9 3.49 0.110 30.550 0.635 SS- wcmt, hem,lim,qtz, gla u,frac 6 45 9985.05 0.28 19.9 10.7 9.3 92.4 1.5 0.0 3.08 0.000 30.550 0.135 SS-wcmt, lim,hem,qtz, glau 6 46 9986.05 0.44 22.2 8.3 6.7 92.0 1.6 0.0 3.34 0.000 30.550 0.190 SS- wcmt, hem,lim,qtz, glau 6 47 9987.05 0.14 14.6 12.6 10.9 87.5 1.6 0,0 3,15 0.000 30.550 0.123 SS- vwcmt,qtz, glau,lim 6 48 9988.05 0.21 19.4 5.7 3.9 93.6 1.8 0.0 3.10 0.000 30.550 0.267 SS- vwcmt,qlz,lim,glau 6 49 9989.05 0.52 28.6 8.4 6.4 94.4 2.0 0.0 3.60 0.000 30.550 0.345 SS-wcmt,hem lim,qtz,glau 6 50 9990.05 0.20 25.1 11,3 9.2 90.7 2.2 0.0 3.54 0.000 30.550 0.278 SS-wcmt,hem lim,qtz,glau " 6 51 9991.05 0.54 26.5 15.8 13.7 85.0 2.1 0.0 3.53 0.000 30.550 0.327 SS-wcmt,hem lim,cCz,glau 6 52 9992.05 0.36 24.3 16.6 14.5 87.9 2.0 0.0 3.38 0.000 30.550 0.277 SS- wcmt, hem lim,cltz, glau 6 53 9993.05 0.20 20.8 7.3 5.2 95.2 2.1 0.0 3.15 0.000 30.550 0.246 SS- wcmt,lim, hem,qtz, glau 6 54 9994.05 0.10 18.4 7.4 4.4 94.1 3.1 0.0 3.04 0.000 30.550 0.330 SS-vwcmt,lim,qlz,occ hem & glau 6 55 9995.05 0.13 18.1 8.8 ... 6.1 92.6 2.7 0.0 2.99 0.000 30.550 0.272 SS-vwcmt,lim,qtz,occ hem & glau '-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MclNTYRE UNIT NORTH SLOPE, ALASKA FILE' BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS ~_~ PERMEABI UTY CORE SMPL DEPTH KAl R # # MD 6 56 9996.05 4.16 20.2 8.7 6 57 9997.05 10.18 16.9 14.0 11.9 84.3 2.1 0.0 2.95 0.000 30.550 0.191 6 58 9998.00 0.77 16.9 9.0 6.0 89.8 3.0 0.0 3.06 0.000 30.550 0.221 6 59 9999.05 1.35 27.2 9.6 6.8 90.3 2.8 0.0 3.55 0.000 30.550 0.422 7 I 10001.05 1.48 26.4 17.0 13.8 88.1 3,1 0.0 3.56 0.000 29.750 0.372 7 2 10002.05 0.71 22.1 12.9 9.3 87.4 3.6 0.0 3,23 0.000 29.750 0,369 7 3 10003.05 0.85 22.3 9.2 6.6 91.6 2.6 0,0 3,21 0,000 29.750 0,258 7 4 1 0004.05 0.22 19.2 7.4 4.2 91.3 3,3 0.0 3.07 0.000 29.750 0.276 7 5 10005.05 0.51 21.4 10,1 7.3 87.4 2.8 0.0 3.40 0.000 29,750 0.277 7 6 1000~ .00 0.69 23.7 12,2 9.6 86.4 2.5 0.0 3.39 0.000 29.750 0.299 7 7 * 10007.05 26.28 16.9 -8.1 -11.1 101.9 3.0 0.0 2.78 0.000 29.750 0.259 7 8 1 0008,05 52.01 20.6 36.1 23.3 56.9 10.9 2.0 2.89 0.056 29.750 0.958 7 9 10009.15 LEAD SLEEVE SAMPLE 2.89 0.095 29.750 ND 7 10 1 0010.00 LEAD SLEEVE SAMPLE 2.90 0.092 29.750 ND 7 11 10011.00 LEAD SLEEVE SAMPLE 2.96 0.079 29.750 ND 7 12 10012.00 LEAD SLEEVE SAMPLE 2.85 0,439 29.750 ND 7 13 10013.00 LEAD SLEEVE SAMPLE 2.86 0.000 29.750 ND 7 14 10014.00 LEAD SLEEVE SAMPLE 2.87 0.000 29,750 ND 7 15 10015.25 LEAD SLEEVE SAMPLE 2.85 0.000 29,750 ND 7 16 10016.25 LEAD SLEEVE SAMPLE 2.84 0.000 29.750 ND 7 16 10016.25 79.00 20.6 22.8 22.8 53.3 0.0 0.0 2.83 0.000 29.750 ND 7 17 10017.10 LEAD SLEEVE SAMPLE 2.86 0.042 29.750 ND 7 18 10018.20 LEAD SLEEVE SAMPLE 2.86 0.000 29.750 ND 7 19 10019.00 LEAD SLEEVE SAMPLE 3.03 0.000 29.750 ND 7 20 * 10(:y20.05 0.44 15.8 22.9 20.8 78.9 2.1 0.0 3.20 0.000 29.750 0.244 ~ % ~ % ~ % ~ GM/CC PPM PPM % 5.7 ~.2 3.0 0.0 2.~ 0.~ ~.5~ 0.3~ DESCRIPTION SS-vwcmt,qtz,glau,ck brn arg gr SS - wcmt, qtz, glau SS- wcmt, qtz, glau,lim,lr hem SS- wcmt, hem,lim,qtz,occ gtau SS- wcmt,hem,lim,qtz,occ glau SS- vwcmt,hem, qtz, lim,occ glau SS- wcmt,hem,lim,qtz,occ glau SS- vwcmt,lim, qtz,glau,occ hem SS-wcmt, hem,lim,qtz, glau,sml vugs SS-wcmt,hem,lim,qtz,glau SS-mod-vwcmt,qtz,sid,glau,tr bE cmt & lim,broken SS-wcmt,cCz,gtau,occ wh chtocc brn arg lam,frac SS-p & vwcmt,qlz,glau,wh chtsid,frac SS-pcmt, qtz,glau,occ wh chtbroken SS-p & vwcmt,qtz,glau,wh chtsid,frac SS-pcmt, qtz,glu,wh ch/filled & open frac SS- pcmt qtz,glau,wh chtfrac SS-mod cmt,qtz,glau,wh chtbrcken SS- vwcmt,qtz, glau,sid,wh cht,frac SS-wcmt,qtz,glau,,occ wh cht SS-wcmt,qtz,glau,,occ wh cht SS-pcmtqtz,gtau,,wh cht, broken SS-vwcmt,qtz,glau,sid,t wh cht SS-vwcmt,qtz,glau,sid,t wh cht & brn cly,frac SS-vwcmt,qtz,glau,sid,t lira ~-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFERTO TEXT FOR DETAJLS 7, CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA DEAN STARK ANALYSIS FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS PERMF___.AFI UTY POROSITY SATURATIONS GRAIN MUD I 1 · · ~ ... MD (%) % ~ % ~ % ~. [ .% ~ [ % ~ GM/CC PPM PPM % DESCRIRT.!ON . . 7 21 1 ~1.25 L~D SLE~ SAMPLE 2.~ 0.~5 ~.7~ ND SS-wcmt,~,¢u,wh cht,~en 7 ~ 1 ~.10 L~D SLE~ SAMPLE 2.85 0.~ 29.7~ ND SS-wcmt,~,¢au,~c wh cht 7 23 1 ~3.~ ~,73 ~.8 11.6 -3.8 51.0 15.4 0.0 2.87 0.~ ~.7~ 1.4~ SS-~cmt,q~,gbu,sid,~ wh cbt 7 24 * 1~4.~ 0.79 17.2 16.5 14.4 ~.4 2.2 0.0 3.25 0.~ ~.7~ 0.186 SS-~cmt,q~,gbu,sid,t ~m 7 25 1~.25 7.~ 16.6 ~.0 ~.3 70.2 4.7 0.0 3.05 0.~ ~.7~ 0.~0 SS-~cmt,q~,gbu,sid,~ brn ~ g ~,vugs 7 ~ 1~.15 B~en 18.4 ~.3 27.5 ~.8 10.8 0.0 3.~ 0.~ ~.7~ 0.626 SS-wcmt,¢,¢u,~wh cmt,b~en 7 27 1 ~7.~ L~D SLE~ SAMPLE 2.~ 0.~ ~.7~ ND SS-mod cmt,q~,g~u,~ ~ cht 7 28 1 ~7.~ L~D SLE~ SAMPLE 2.~ 0.~ ~.7~ ND SS-pcmtq~,¢u,~c bk cmt,t lim,~en 7 ~ * 1 ~31 .~ 0.40 11.2 40.3 37.7 70.2 2.6 0.0 3.08 0.~ ~.7~ 0.1 ~ SS-~cmt,q~,gbu,sid,bn arg gr 7 ~ 1 ~32.25 0.79 23.4 12.9 10.9 ~.5 2.0 0.0 3.53 0.~ ~.7~ 0.~5 SS-wcmt,h~,lim,q~,~ gbu 7 31 1~.05 1.13 ~.3 19.2 17.2 ~.7 2.0 0.0 3.28 0.~ ~.750 0.276 SS-wcmt,lm,q~,~ gbu,t hem 7 32 1 ~.25 L~D SLE~ SAMPLE 2.82 0.~ ~.7~ ND SS-wcmt,~,¢u,sid,brn cly 7 ~ 1 ~35.05 42.~ 16.1 47.5 ~.6 60.4 3.9 0.0 3.03 0.~ ~.750 0.275 SS-~cmt,q~,gbu,sid,~n cly,vugs 7 ~ 1 ~.05 86.~ 17.7 62.5 58.8 46.4 3.6 0.0 3.01 0.~ ~.7~ 0.274 SS- w- ~cmt q~, Cu,sid,ffac 7 ~ 1 ~7.05 ~.39 17.3 42.2 ~.7 ~.8 6.2 2,3 2.~ 0.059 ~.7~ 0.495 SS-w-~cmtq~,¢u,sid,bn ~g ¢ 7 ~ 1 ~.15 12.~ 18.7 ~.0 19.0 78.6 3.0 0.0 3.14 0.~ ~.7~ 0.~2 SS-vcmt,~, gbu, sid,brn ~ g ¢,vugs 7 37 1~.~ 14.62 ~.2 81.8 ~.1 ~.6 4.7 0.0 3.~ 0.~ ~.7~ 0.352 SS-vcmt,~,g~u,sid,brn ~g ¢ 7 ~ * 1~.15 ~en 27.5 ~.0 ~.5 14.5 2.5 0.0 3.~ 0.~ ~.7~ 0.323 SS-p-~cmLq~,~n cly,sid,~en 7 39 1 ~1.1 5 14.~ 17.4 44.9 41.6 ~.4 32 0.0 3.23 0.~ ~.7~ 0.~1 SS- vcmt,~,g~u,sid,brn ~g ¢ 7 ~ 1~,15 21.31 17.6 ~.4 ~.1 59.6 9.3 0.0 3.15 0.~ ~.7~ 0.795 ~-~cmt,q~,gbu,sid,~ ~ cmt 7 41 1 ~.~ 46.05 17.8 37.7 ~.6 51.5 11.1 0.0 3.14 0.~ ~.7~ 0.9~ SS-~cmt,q~,gbu,sid,~ ~ cmt 7 42 1 ~.15 ~.35 16.4 40.7 25.6 ~.9 12.9 2.1 3.13 0.059 ~.7~ 1.1 30 SS- wcmt,~, Cu,sid,~ hem 7 ~ 1~45.05 7.44 13.6 41.9 32.8 51.5 9.1 0.0 3.11 0.~ ~.7~ 0.6~ SS-wcmt,~,¢au,sid,~ lim,wh cht 7 44 * 1~.05 ~en 13.7 61.6 ~.4 37.7 2.2 0.0 3.25 0.~ ~.7~ 0.181 SS-p-~cm[q~,Mk cmt,brn cly,~en 7 45 1 ~7.05 ~en 14.2 28.9 24.4 ~.9 4.5 0.0 3.10 0.~ ~.7~ 0.~ SS-~cmt,q~,~d,wh cmt,~ ~n cly,s~ vugs,~en , , *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLb-f'ED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA CORE LABORATORIES FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERMEABILITY POROSITY SATURATIONS GRAIN MUD CORE SMPL DEPTH KAIR (HEUUM) OiL I COROIL~ wATERI HEXAD.,FtLTRA. DENSITY TRACER TRACER HEXAD. ....#.. .# FT MD (%) .... % Pv .% Pv / % Pv 1% Pv 1% Pv GM/CC PPM PPM % DESCRIPTION ..... 7 46 10048.05 Broken 23.1 10.8 8.4 88.8 2.4 0.0 3.39 0.000 29.750 0.460 Cgl-vwcmt, lim,qtz,t bk vit cmt & hem,broken 7 47 10049.05 0.82 18.6 8.5 6.6 88.0 1.9 0.0 3.37 O.O(X) 29.750 0.157 Cgl-wcmt, lim,qtz,tr glau 7 48 10050.15 0.89 18.0 10.2 7.8 85.5 2.5 0.0 3.13 0.000 29.750 0.216 SS-wcmt, qtz,glau,occlim,lr hem 7 49 10051.05 Broken 21.1 No Data 1.7 0.0 3.41 0.000 29.750 0.174 Cgl-wcmt, lim,qtz,occ hem,lr bi( FeSi,brcken 7 50 1 0052.05 0.42 18.9 1 5.1 13.3 87.6 1.7 0.0 3.24 0.000 29.750 0.171 C gl-vwcrnt, lim,qlz,glau ,tr hem 7 51 1 0053.20 14.13 21.3 29,3 26.6 75.4 2.6 0.0 3.09 0.000 29.750 0.275 Cgl- vwcmt,lim,qtz,glau,t hem,vugs 7 52 1 0054.05 114,57 20.3 20.9 16.6 60.3 4.3 0.0 3.06 0.000 29.750 0.375 SS-mod to vwcmt, qtz,glau,sid,frac 7 53 1 0055.05 34.08 17.2 37.2 30.1 57.7 7.0 0.0 2.83 0.000 29.750 0.535 SS-vwcmt,qtz,glau,brn arg ~r 7 54 10056.25 Broken 20.7 35.9 27.3 51.5 4.3 4.3 2.95 0.157 29.750 0.499 SS-mod to vwcmt,qtz,glau,sid, bk FeSi cmt,broken 7 55 1 0057.05 5.80 15.3 26.1 19.6 73.8 3.9 2.6 2.87 0.065 29.750 0.311 SS- vwcmt,qtz,glau,sid 7 56 * 10058.05 2.02 14.3 22.6 19.2 76.2 3.4 0.0 2.93 0.000 29.750 0.218 SS-vcmt,qtz,glau, sid~-r c~y gr 7 57 10059.05 Broken 12.4 38.3 26.9 95.4 5.4 6.1 2.92 0.111 29.750 0.312 SS-mod to vwcrnt,qtz,glau,sid, bk FeSi cmt,broken 7 58 * 10060.00 68.14 25.0 33.5 31.3 47.7 2.2 0.0 3.08 0.000 29.750 0.258 SS-mod to vwcmt,qtz,glau,sid, brn arg (jr,broken 7 59 1 0061.05 1.06 25.7 13.2 7.7 90.7 1.7 3.9 3.47 0.139 29.750 0.192 SS-wcmt,im,qtz,glau 7 60 1 0062.05 0.54 21.9 8.0 6.2 90.5 1.9 0.0 3.45 0.000 29.750 0.174 SS- wcmt, im,qtz, gtau,occ hem 7 61 10063.25 0.28 21.1 11.3 9.7 89.2 1.6 0.0 3.46 0.000 29.750 0.149 SS-wcmt, im,qtz,gtau,occ hem 7 62 10064.05 0.51 20.0 10.8 7.3 88.6 2.4 1.2 3.36 0.052 29.750 0.340 SS-wcmt, lim,qtz,glau,lr hem 7 63 10065.05 1.91 20.3 11.3 8.6 84.1 2.6 0.0 3.10 0.000 29.750 0.263 SS- wcmt, lim, qtz,gtau,tr hem 7 64 10065.85 0.66 26.0 13.2 12.0 86.3 1.2 0.0 3.44 0.000 29.750 0.140 SS-wcmt,tim,qtz,glau,lr hem 7 65 10067.05 0.18 24.6 6.8 1.5 92.7 0.9 4.4 3.56 0.170 29.750 0.108 SS- vwcmt,hem,lim, qtz, glau 7 66 1 0068.05 0.44 28.3 12.1 9.5 90.8 1.3 1.3 3.61 0.057 29.750 0.181 SS-vwcmt,hem,lim, qtz, glau 7 67 1 0069.05 0.42 25.2 7.7 4.7 93.9 1.8 1.3 3.51 0.050 29.750 0.225 SS- vwcmt,hem,lim, qtz,glau 7 68 10070.05 0.59 27.1 13.5 11.9 89.5 1.6 0.0 3.65 0.000 29.750 0.189 SS- vwcmt,lim, g!au,qtz,occ hem 7 69 1 0071.05 0.54 22.7 7.3 1.5 93.4 2.4 3.5 3.43 0.160 29.750 0.357 SS-vwcmt,lim,hem,gtau,qtz, wh cmt filled ~t 7 70 1 0072.00 2.30 21.8 13.0 7.7 81.9 5.3 0.0 3.16 0.000 29.750 0.624 SS- wcmt,lim, qtz, gta u *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS "": i~E'~':~STARK ANALYSIS PERMEAB UTY POROSITY SATURATIONS GR,NN MUD , # # ..... FT .... MD (%) % Pv % Pv / % Pv % Pv [ % Pv GM/CC,,, PPM PPM .... % DESCRIPTION 7 71 10073.05 5.64 27.2 15.4 10.3 82.5 5.0 0.0 3.23 0.000 29.750 0.621 SS- wcmt, lim, qtz, glau, occ hem 7 72 10074.05 7.10 21.2 20.2 15.6 77.6 4.6 0.0 3.08 0.000 29.750 0.450 SS-wcmt,qtz,lim,glau 7 73 1 0074.85 3.36 22.4 13.1 9.1 86.5 4.0 0.0 3.04 0.000 29.750 0.426 SS- wcmt, qtz,lim, glau 7 74 1 0076.25 4.08 22.3 11.2 5.3 83.7 3.8 2.1 3.07 0.063 29.750 0.361 SS-w to vwcmt, qtz,glau,lim Ir hem 7 75 1 0077.05 3.79 20.0 10.2 3.6 87,1 4.2 2.4 3.17 0.064 29.750 0.363 SS-w to vvccmt, qtz,glau,lim Ir hem 7 76 1 0078.00 17.19 23.2 15.0 7.3 81.5 5.3 2.4 3.04 0.071 29.750 0.497 SS-w to vwcmt,qlz,glau,sid,~' lira 7 77 1 0079.05 1.42 13.5 14.8 11.1 76.6 3.7 0.0 2.80 0.000 29.750 0.254 SS-vwcmt,qtz,glau,occ brn ch/ 7 78 1 0080.05 7.05 18.8 19.1 13.4 75.1 3.8 1.9 2.98 0.051 29.750 0.316 SS-vwcmt,qtz,glau,occ brn cly,tr pyr 7 79 1 0081.05 3.37 18.4 9.2 5.6 85.2 3.5 0.0 3.02 0.000 29.750 0.311 SS-vwcmt,qtz,glau,sid,br n cly,occ wh cht 7 80 1 0082.05 29.46 18.5 18.2 11.4 73.7 6.8 0.0 2.93 0.000 29.750 0.519 SS-vwcmt,qtz,glau,sid,wh cht,occ brn cly 7 81 1 0082.95 0.73 13.3 8.7 5.0 82.5 3.7 0.0 3.14 0.000 29.750 0.291 SS-vwcmt,qtz,glau,sid,occ wh cbt 7 82 1 0084.05 73.59 20.2 24.0 13.2 68.2 10,8 0.0 2.90 0.000 29.750 0.971 SS- vwcmt,qtz,glau,sid,occ wh cbt 7 83 10085.15 28.27 18.1 20.7 10.7 66.2 10.0 0.0 2.84 0.000 29.750 0.818 SS-vwcmt,qtz,glau,occ wh cht 7 84 1 0086.05 69.69 22.3 24.4 8.9 69.3 15.5 0.0 2.84 0.(X)0 29.750 1.795 SS-wcmt, qtz,glau,occ wh cbt 7 85 1 0087.00 52.35 21.3 25.6 12.8 65.9 12.7 0.0 2.80 0.000 29.750 1.388 SS- wcmt, qtz,glau,occ wh cbt 7 86 1 0088.05 0.01 15.6 3.5 1.1 73.1 2,4 0.0 3.15 0.000 29.750 0.327 SS-wcmt,qtz,glau,sid,occ wh cbt 7 87 1 0089.25 66.98 21.5 31.9 19.9 53.1 12.0 0.0 2.75 0.000 29,750 1.409 SS- wcmt, qtz,occ wh cbt 7 68 10090.05 86.47 23.1 35.5 20.2 50.9 15.3 0.0 2.73 0.0OO 29.750 1.656 SS-wcmt,qtz,occ wh chtwk brn cly lam 8 1 1 0090.00 136.49 25.5 21.4 13.2 65.1 8.3 0.0 2.80 0.000 34.150 1.085 SS-wcrnt, qtz,occ wh cbt 8 2 1 O091.05 68.47 22.9 23.3 17.2 60.5 6.1 0.0 2.85 0.000 34.150 0.714 SS-wcmt,qtz,occ wh cbt 8 3 1(X~2.15 11.72 21.7 29.1 20.7 52.1 8.4 0.0 2.78 0.000 34.150 0.899 SS- wcmt, qtz,occ wh cht 8 4 1 0093.00 7.53 20.5 27.5 21.5 52.0 6.0 0.0 2.81 0.000 34.150 0.686 SS-vwcmt,qtz,wh cht 8 5 10094.05 4.20 24.3 41.4 37.6 59.5 3.8 0.0 3.00 0.000 34.150 0.462 SS-wcmt,qtz,glau,wh cht 8 6 10095.00 0,96 17.0 24.5 21.1 48.2 3.4 0.0 2.96 0.0OO 34.150 0.290 SS- vwcmt,qtz,occ wh cht, wh cmt 8 7 10097.05 4.75 19.3 22.3 18.1 63.2 4.2 0.0 2.86 0.000 34.150 0.368 SS-vwcmt,qtz,wh cht & cmt,brn cly lam,ir glau. *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAJNTS- REFER TO TEXT FOR DETAJLS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS PERM EAEI LITY POROSITY SATURATIONS GRAIN MUD CORE SMPL DEPTH KAIR (HELIUM) OIL 1COROI WATER HEXAD. RLTRA. DENSITY TRACER TRACER HEXAD. # # FT MD (%) %.Pv..I % Pv / % Pv % Pv [ % Pv GM/CC .. PPM PPM .%. DESCRIPTION 8 8 10098.25 2.98 19.1 24.8 20.2 56.7 4.6 0.0 2.77 0.000 34.150 0.382 SS-vwcmt,qtz,wh cbt & cmt,brn cly lam 8 9 10098.90 0.94 13.9 22.2 16.6 59.7 5.6 0.0 2.90 0.000 34.150 0.377 SS-vwcmt,qtz,wh cbt & cmt, brn cly lam 8 10 10100.20 16.40 25.0 25.5 19.4 50.2 6.0 0.0 2.93 0.000 34.1 50 0.690 SS- wcmt, qtz,wh cbt wh cmt,tr glau 8 11 10101.05 4.06 20.5 26,6 18.8 53.2 7.8 0.0 2.85 0.000 34.150 0.809 SS- vwcmt,qtz,wh cht,wh cmt 8 12 10102.05 14.03 21.3 26.5 18.0 55.6 8.5 0.0 2.75 0.000 34.1 50 0.872 SS- vwcmt,qtz,wh cht 8 13 10103.05 2.24 15.9 30.8 23.7 56.0 7.1 0.0 2.75 0.000 34.150 0.529 SS-vwcmt,qtz,wh cht,v~ brn ch/lam 8 14 1 0104.20 1.60 14.6 32.4 27.9 53.6 4.6 0.0 2.73 0.000 34.150 0.301 SS-vwcmt,qtz,wh cht,wk brn cly lam 8 15 10105.05 94.38 22.2 23.1 12.1 55.2 11.0 0.0 2.93 0.000 34.1 50 1.31 9 SS- vwcmt,qtz,wh cht,wh cmt 8 16 10106.15 95.48 21.9 32.6 17.0 51.5 15.6 0.0 2.91 0.000 34.150 1.688 SS-vwcmt,qtz,wh cht,wh cmt 8 17 10107.25 71.46 23.5 41.3 24.1 46.6 17.1 0.0 2.73 0.000 34.150 2.162 SS- vwcmt,qtz,wh cht,t glau 8 18 10108.05 30.19 21.5 36.3 23.9 53.5 12.4 0.0 2.71 0.000 34.150 1.283 SS-vwcmt,qtz,wh cht,,/,k brn cly lam 8 19 10109.00 354.87 26.8 37.5 17,6 56.9 19.9 0.0 2.72 0.000 34.150 2.862 SS-mod to wcmt~qtz,wh cht,tr glau 8 20 10110.25 52.57 21.4 38.5 20.1 51.5 18.4 0.0 2.72 0.000 34.150 2.399 SS-vwcmt,qtz,wh cht,occ brn cly lam,t glau 8 21 10111.00 323.73 25.9 34.7 13.6 60.1 21.1 0.0 2.81 0.000 34.150 2.472 SS-mod to wcmtqtz,wh cht,'~ glau 8 22 10112.05 150.32 25.3 33.7 16.9 59.9 16.9 0.0 2.71 0.003 34.150 2.046 SS-wcmt,qtz,wh chtglau 8 23 10112.85 1.16 20.4 30.0 18.4 49.9 11.6 0.0 2.99 0.000 34.150 1.022 SS-vwcmt,qtz,whcht,occ glau 8 24 10114.05 0.9~ 17.8 23.5 18.9 57.8 4.6 0.0 3,03 0.000 34.150 0.466 SS-wvcmt,qtz,wh cht,wh cmt 8 25 10115.00 91.90 23.1 31.1 14.0 61.7 17.2 0.0 2.73 0.000 34.150 1.942 SS-wcmt,qtz,glau,occwh cht 8 26 10116.25 109.31 23.6 37.3 19.5 57.5 17.8 0.0 2.74 0.000 34.1 50 1.787 SS- mod to wcmt, qtz,wh cht,glau 8 27 10117.05 108.85 20.8 42.1 31.0 50.3 11.1 0.0 2.82 0.000 34.150 0.898 SS- wcmt, qtz,wh cht. glau 8 28 10118.00 35.57 18.2 42.4 28.1 46.2 14.3 0.0 2.72 0.000 34.150 1.089 SS-wcmt,qtz,wh cht, glau,occ brn cly lam 8 29 10120.05 18.17 17.9 37.3 24.5 50.0 12.8 0.0 2.76 0.000 34.150 0.977 SS-vwcmt,qtz,wh cht, giau,occ brn c¥ lam 8 30 10121.05 57.38 22.3 43.2 32.5 39.0 10.8 0.0 2.85 O.O(X:) 34.150 1.066 SS- vwcmt,qtz,wh cht, giau 8 31 10122.05 13.05 19.8 36.7 26.1 50.5 10.6 0.0 2.88 0.000 34.150 0.918 SS-vwcmt,qtz,wh cht,glau,occ br n cty lam 8 32 10123.05 16.87 20.3 37.2 24.5 48.8 12.7 0.0 2.92 0.000 34.1 50 1.237 SS -vwcmt,qtz,wh cht, gla u . *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERMEAEIUTY POROSITY SATURATIONS .... GRAIN MUD · l # # ~... MD (%) % ~ % ~ / % ~ % ~ 1% ~ GM/CC PPM i PPM,, . % DESCRI~ION .. 8 ~ 10124.05 ~.07 21.5 ~.2 ~.6 47.0 16.5 0.0 2.78 0.~ ~.1~ 1.3~ SS-~cmt,~,wh cht,~u 8 ~ 10125.~ 62.~ 21.3 43.5 25.7 44.2 17.8 0.0 2.70 0.~ ~. 150 1 .~5 SS- ~cmt,q~,wh cht.~u 8 35 10126.~ 93.75 23.7 45.1 27.2 47.2 17.9 0.0 2.73 0.~ ~.1 ~ 1.826 SS-~cmt,q~,wh cht,~au,~c ~ n c~ ~m 8 ~ 10127.~ 94.23 19,7 53.8 ~.2 36.6 24.5 0.0 2.69 0.~ ~.150 1 .~1 SS- ~cmt,q~,wh cht,~u 8 37 10127.95 37.13 19.7 41.4 ~.7 52.1 11.7 0.0 2.69 0.~ ~,1 ~ 1.324 SS- ~cmt,q~,wh cht,~au 8 ~ 101~.05 40.93 18.8 ~.0 28.0 42.3 11.0 0.0 2.80 0.~ ~.1~ 0.~7 SS-~cmt,q~,~ cht,~u 8 ~ 101~.~ ~.11 21.0 31.7 24.3 52.1 7.3 0.0 2.67 0.~ ~.1 ~ 0.719 SS-~cmt,q~,wh cht,~u,~c ~n c~ ~m 8 40 10132.05 18.~ 17.8 ~.6 24.5 51.7 12.2 0.0 2.69 0.~ ~.1~ 0.~1 SS-~cmt,q~,wh cht,~u,~c ~n c~ ~m 8 41 101~.05 182.28 22.5 52.1 ~.8 37.6 21.3 0.0 2.69 0.~ ~.1~ 2.240 SS-~cmt,~,wh cht,~u 8 42 101~.~ 1~.~ ~.4 ~.6 24.5 42.6 ~.0 0.0 2.71 0.~ ~.1~ 2.~ SS-~cmt,q~,whcht,~u,~c ~n c~ ~m 8 ~ 101~.05 3.57 ~.9 ~.2 16.8 61.6 5,4 0.0 2.~ 0.~ ~.1~ 0.~ SS-~cmt,q~,wh cht,~u,~g gr,~c ~n cly ~m 8 ~ 101~.~ ~.~ 21.7 ~.9 17.0 56.8 11.1 2.8 2.~ 0.~ ~.1~ 1.~ SS-~cmt,~,~ cht,~u,kac 8 ~ 101~.95 1~.~ ~.1 ~.8 14.8 ~.8 ~.0 0.0 2.71 0.~ ~.1~ 1.~9 SS-~cmt,q~,~ cht,~ g~u,~ac 8 ~ 101~.05 141.~ 21.9 28.9 15.4 49.0 13.5 0.0 2.75 0.~ ~.1~ 1.376 SS-~cmt,q~,~ cht,~ g~u 8 47 101~.95 149.61 21.6 37.2 ~.5 ~.1 16.7 0.0 2.67 0.~ ~.1~ 1.6~ SS-~cmt,q~,wh cht,~ g~u,~c ~n c~ ~m 8 ~ 101~.~ 107.~ 21.2 ~.6 21.3 ~.6 15.3 0.0 2.75 0.~ ~.1~ 1.351 SS-~cmt,q~,wh cht,~ g~u,tr ~n c~ 8 49 10141.05 ~.76 21.0 35.4 19.9 49.4 15.6 0.0 2.71 0.~ ~.1 8 ~ 10142.15 132.~ ~.1 42.6 25.0 45.5 17.6 0.0 2.82 0.~ ~.1~ 1.4~ SS-~cmt,q~,~ cht,~ g~u,~c ~n c~ ~m 8 51 101 ~.~ 1 ~.49 ~.3 41.0 25.1 ~.2 15.9 0.0 286 0.~ ~.1 ~ 1.7~ SS- ~cmt,~,wh cht,~ g~u 8 52 101~.95 2~.~ 25.6 35.2 17.6 ~.0 17.6 0.0 2.82 0.~ ~.1~ 2.127 SS-~cmt,~,wh cht,~u,~ en 8 ~ 10147.05 971.57 28.0 27.1 14.8 ~.2 12.2 0.0 2.~ 0.~ ~.1 ~ 1 .~5 SS-wcmt,~,~ chi g~u 8 ~ 101 ~.05 6.~ 19.8 19.0 11.8 ~.6 7.2 0.0 3.01 0.~ ~. 1 ~ 0.~ SS- ~cmt,~,wh cht,~u 8 ~ 10151.05 3.~ 14.3 ~.8 24.1 49.1 8.7 0.0 2.~ 0.~ ~.1~ 0.~5 SS-~cmt,q~,~ cht,~ g~u 8 ~ 101 ~.~ 79.~ ~.9 ~.8 18.3 48.9 14.6 1.9 2.~ 0.059 ~. 1 ~ 1.232 SS-~cmt,q~,wh cht,~ g~u 8 57 101~.05 65.76 ~.9 ~.3 10.2 55.0 24.1 0.0 276 0.~ ~.1~ 1 .~ SS-~cmt,q~,wh cht,~u *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSfS:PB,DS, FE,TR,DS CORE SMPL # # DEAN STARK ANALYSIS PERMEAB LITY POROSITY SATURATIONS GRAIN MUD .. Fl' ,MD (%) .... %PvI'%Pv.J %IN,l'%Pv 1%Pv GM/CC PPM PPM ,. % 8 58 10154.05 136.17 22.8 29.4 10.8 54.5 18.6 0.0 2.77 0.000 34.150 1.954 8 59 1 01 55.05 148.82 21.8 28.3 8.4 54.2 1 9.8 0.0 2.69 0.000 34.1 50 1.764 8 60 1 01 56.05 79.95 20.5 29.5 14.2 53.4 15.2 0.0 2.70 0.000 34.1 50 1.301 8 61 10157.05 107.30 20.8 27.9 8.2 56.8 19.8 0.0 2.69 0.000 34.150 2.296 8 62 * 1 01 56.00 2.66 14.4 33.7 25.9 45.5 7.8 0.0 2.96 0.000 34.1 50 0.455 8 63 1 0159.05 101.28 20.3 28,2 6.3 50.1 21.9 0,0 2.75 O.(:X)O 34.1 50 1.869 8 64 10160.05 101.26 20.4 28.3 8.6 55.5 19.7 0.0 2.72 0.000 34.150 1.603 8 65 10161.05 21.69 18.5 26.4 13.3 57.4 13.1 0.0 2.78 0.000 34.150 0.970 8 66 10162.25 25.46 18.4 25.2 12.5 56.0 12.7 0.0 2.83 0.000 34.150 0.958 8 67 10163.05 102.29 20.7 29.8 7.4 53.2 22.4 0.0 2.71 0.000 34.150 1.985 8 68 1 01 64.05 82.40 19.8 26,8 7.6 53.0 19.2 0.0 2.72 0.000 34.1 50 1.551 8 69 10165.05 69.61 18.8 27.5 11.5 48.6 15.9 0.0 2.76 0.000 34.150 1.300 8 70 1 01 68.05 95.21 20.7 28.4 9,2 57.5 19.2 0.0 2.72 0.000 34.1 50 1.707 8 71 10167.05 54.59 17.1 46.2 28.0 36.3 18.1 0.0 2.71 0.000 34.150 1.255 8 72 10169.05 55.63 18.9 31.6 12.0 49.5 19.6 0.0 2.70 0.000 34.150 1.519 8 73 10169.95 99.47 19.2 29.1 8.5 51.3 20.7 0.0 2.71 0.000 34.150 1.610 8 74 10171.00 33.76 17.1 31.6 13.7 52.1 17.9 0.0 2.70 0.000 34.150 1.228 8 75 10172.05 29.80 17.1 31.9 16.7 50.8 15.2 0.0 2.68 0.000 34.150 1.089 8 76 1 0173.05 130.37 21.3 42.4 18.4 44.0 23.9 0.0 2.75 0.000 34.1 50 2.155 8 77 10174.25 44.85 18.0 32.0 15.0 52.0 16.9 0.0 2.67 0.000 34.150 1.306 8 78 10176.25 51.39 18.2 31.8 12.4 51.8 19.4 0.0 2.71 0.000 34.150 1.467 8 79 10177.05 58.52 18.4 28.0 9.5 50.5 18.5 0.0 2.73 0.000 34.150 1.574 8 80 10177.90 4245 18.4 41.6 15.3 46.1 26.2 0.0 2.80 0.000 34.150 2.026 9 1 1 0179.05 111.78 20.0 23.4 14.9 46.1 8.5 0.0 2.77 0.000 32.600 1.074 9 2 10180.00 35.98 16.9 25.2 15.8 48.7 9.3 0.0 2.69 0.000 32.600 0.805 DESCRIPTION SS-vwcmt,( SS-vwcmt,c SS-vwcmt,( SS- vwcmt,c SS-vwcmt,c SS-vwcmt,c SS- vwcmt,¢ SS-vwcmt,¢ SS- vwcmt,¢ SS- vwcmt,¢ SS-vwcmt,( SS-vwcmt,( SS-vwcmt,( SS-vwcmt,( SS- vwcmt,( tz,wh cht,occ glau tz,wh cht,occ glau,wk brn cly lam tz,wh cht,occ glau,wk brn ch/lam tz,wh cht,occ glau,wk brn cly lam,t, sid tz,wh cht,occ glau,tr sid tz,wh cht,ooc glau,wk brn ch/lam tz,wh cht,occ glau tz,wh cht,glau tz,wh cht,occ glau tz,wh cht,occ glau tz,wh cht,ooc glau tz,wh cht,occ glau ftz,wh cht, glau tz,wh cht,occ glau tz,wh cht,occ glau SS-vwcmt,ctz,wh cht,occ glau SS-vwcmt,ctz,wh cht,occ glau,wk brn ch/lam SS-vwcmt,qtz,wh cht,occ glau,wk brn cly lam SS-vwcmt,qtz,wh cht,occ glau,wk brn cly lam SS-vwcmt,qtz,wh cht,occ glau,wk brn ch/lam SS-vwcmt,qtz,wh cht,occ glau,wk brn cly lam SS-vwcmt,qtz,wh cht,occ glau,wk brn cly lam SS-vwcmt,qtz,wh cht,occ glau SS-vwcmt,qtz,wh cht,occ glau SS-vwcmt,qtz,wh cht,ooc gLau,wk brn ch/lam *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFERTO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. Mcl NTYRE UNIT NORTH SLOPE, ALASKA DEAN STARK ANALYSIS PERMEABIUTY POROSITY ......... R O{ W HEXAD. FILTRA. DENSITY TRACER TRACER HEXAI CORE SMPL DEPTH KAIR (HELIUM) OIL Cu ~TER # # I _F'T _.. MD (%~_. % Pv J % Pv J % Pv J . % Pv % Pv GM/CC PPM PP.M.. % 9 3 10181.15 57.85 18.6 21.7 16.0 50.0 5.7 0.0 2.68 0.000 32.600 0.424 9 4 10182.05 63.87 17.6 34.2 12.3 42.7 21.9 0.0 2.72 0.000 32.600 1.576 9 5 1018,3.25 57.58 18.4 36.4 15.2 44.6 21.2 0.0 2.82 0.000 32.600 1.616 9 6 10184.20 63.79 19.7 32.1 12.9 49.3 19.1 0.0 2.80 0.000 32.600 1,530 9 7 10185.05 41.06 17.7 30.7 18.6 47.2 12.1 0.0 2.78 0.000 32.600 0.883 9 8 10186.25 103.87 19.6 25.0 10.5 54.4 14.6 0.0 2.68 O.(:X:)O 32.600 1,168 9 9 10187.00 Broken 19.7 32.3 16,7 49.5 13.8 1.7 2.87 0.045 32.600 1,051 9 10 10188.05 230.34 20.1 37.9 13.0 46.1 20.4 4.5 2.74 O. 128 32.600 1.663 9 11 1 0189.05 1311.43 21.2 31.9 12.2 50.2 17.8 1.9 2.68 0.053 32.600 1.468 9 12 10189.95 44.98 17.5 28.3 10.4 56.7 16.0 1.9 2.69 0.049 32.600 1,175 9 13 1 0190,95 99.57 18.0 45.5 31.6 38.3 12.4 1.5 2.90 0.049 32.600 1.1 75 9 14 1 0191.95 Broken 18.1 31.4 17.8 51.2 12.0 1.6 2.79 0.044 32.600 0.959 9 15 10193.00 3.96 14.9 36.6 28.6 44.6 8.0 0.0 2.94 0.000 32.600 0.922 9 16 1 0194.25 403.79 19.2 31.1 13 8 52.8 15.6 1.6 2.76 0.054 32.600 1.488 9 17 10194.95 140.48 20.1 34.7 14.3 47.3 16.3 4.1 2.71 0.135 32.600 1.573 9 18 10196.25 548.14 20.0 27.4 12.4 54.4 13.6 1.5 2.69 0.043 32.600 1.153 9 19 1 0197.15 Broken 20.4 31.2 10.1 53.4 19.3 1.8 2.69 0.054 32.600 1.671 9 20 1 0197.95 34.69 18.5 26.8 14.1 53.2 11.0 1.6 2.89 0.049 32.600 0.944 9 21 10199.00 140.59 19.0 30.2 10.7 56.5 16.2 3.3 2.69 0.102 32.600 1.456 9 22 1 0200.00 235.51 18.3 32.2 11,4 53.6 18.7 2.0 2.81 0.058 32.600 1.567 9 23 1 0201.05 7.15 16.7 25.3 16.6 54.5 8.7 0.0 2.72 0.000 32.600 0.690 9 24 1 0202.00 3.85 14.7 27.5 20.5 54.2 7.0 0.0 2.71 0.000 32.600 0.464 9 25 1 0203.05 1.85 13.5 31.0 24.8 53.6 6.2 0.0 2.71 0.000 32.600 0.435 9 26 1 0204.05 5.65 14.2 33.9 24.5 51.9 9.3 0.0 2.72 0.000 32.600 0.5,38 9 27 10205.25 15.26 17,2 29.3 17.6 51.2 11.7 0.0 2.76 0.000 32.600 0.863 FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DESCRIPTION SS-vwcmt,qtz,wh cht,occ glau,wk brn cly lam SS-vwcmt,qtz,wh cht,occ glau SS-vwcmt,qtz,wh cht,occ glau SS-vwcmt,qtz,wh cht,occ glau SS-vwcmt,qtz,wh cht,occ glau,wk brn cly lam SS-vwcmt,qtz,wh cht,occ glau SS-vwcmt,qtz,wh cbt,otc glau,broken SS-vwcmt,qtz,wh cht,occ glau,wk brn ch/lam,fac SS-vwcmt,qtz,wh cht,occ glau,wk brn cly lam,brck en SS-vwcmt,ctz,wh cht,occ glau,wk brn cly lam,broken SS-vwcmt,ctz,wh cht,occ glau,frac SS-vwcrnt,¢tz,wh cht,occ glau,wk brn cly lam,~oken SS-vwcrnt,¢ tz,wh cht,occ glau,sid SS-vwcmt,¢ tz,wh cht,occ glau,frac SS-vwcmt,¢ tz,wh cht,occ glau,frac SS-vwcmt,¢ tz,wh cht,occ glau,frac SS-v'wcmt,¢ tz,wh cht,occ glau,wk brn cly lam,broken SS-vwcmt,¢:tz,wh cht,glau SS-vwcmt,qtz,wh cht,glau,~r ac SS-vwcrnt,qtz,wh cht,glau,lr ac SS-vwcmt,qtz,occ wh cht& glau,wk brn cly lam SS-vwcmt,qtz,occ wh cht& gtau,v~ brn cly [am SS-vwcmt,qtz,occ wh cht& gtau,v~ brn cly lam SS-vwcmt,qtz,occ wh cht& glau,v~ brn ch/lam,fi"ac SS-vwcrnt,qtz,occ wh cht& gtauJr brn ch/ *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MclNTYRE UNIT NORTH SLOPE, ALASKA FILE: BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS PERMEABUTY POROSITY SATURATIONS GR/~N MUD .......-- . ,,, , CORESMPL DEPTH KAIR ,HEUUM, OIL IOOROIL~ WATER[ HEXAD:IRLTRA. DENSITY TRACER TRACER HEXAD. . .~ . # FT MD . .. (%) %PvJ/%Pv %Pr~1%Pv J~ %Pv GM/CC PPM PPM % DESCRIPTION 9 28 10206.05 8.66 15.2 29.9 18.2 53.7 11.7 0.0 2.74 0.000 32.600 0.762 SS-vwcmt,qtz,occ wh cbt & glau,tr brn ch/ 9 29 10207.10 4.46 14.6 29.6 20.8 51.9 8.8 0.0 2.73 0.000 32.600 0.545 SS-vwcrnt,qtz,occ wh cbt & glau,t brn ch/ 9 30 10208.05 47.90 18.3 32.5 16.4 48.6 16.1 0.0 2.67 0.000 32.6(:X) 1.282 SS-vwcmt,qtz,occ wh cht & glau,t brn cly 9 31 10209.05 28.52 17.8 28.5 10.1 51.0 16.3 2.1 2.71 0.069 32.600 1.590 SS-vwcmt,qtz,occ wh cht & glau,~ brn cly 9 32 10209.95 1.79 14.2 29.0 No Dala 57.6 No Data 0.0 2.72 O.O(X) 32.600 No Data SS-vwcrnt,qtz,occ wh cbt & glau,lr brn cly 9 33 10211.05 1.31 12.6 30.2 22.1 55.3 8.1 0.0 2.73 0.000 32.600 0.473 SS-vwcmt,qtz,occ wh cht & glau,t brn cly 9 34 10212.00 1.46 13.4 28.4 22.3 57.2 6.1 0.0 2.71 0.000 32.600 0.386 SS-vwcmt,qtz,occ wh cbt & glau,t brn ch/ 9 35 10212.95 18.14 16.0 30.8 16.3 53.7 14.5 0.0 2.73 0.000 32.600 0.950 SS-vwcmt,qtz,occ wh cbt & glau,t brn ch/ 9 36 10214.20 0.72 11.7 28.5 20.3 57.9 8.2 0.0 2.76 0.000 32.600 0.456 SS-vwcmt,qtz,occ wh cbt & glau,b~n cly 9 37 10215.00 33.10 18.4 16.7 2.2 49.8 12.8 1.7 2.69 0.050 32.600 1.123 SS-vwcmt,qtz,occ wh cbt & glau,t brn cly 9 38 10215.95 109.64 18.7 25.3 9.8 51.5 15.4 0.0 2.67 0.000 32.600 1.151 SS-vwcmt,qtz,occ wh cbt & glau,t brn cly 9 39 10217.05 56.10 16.6 32.7 18.2 51.6 14.5 0.0 2.71 0.000 32.600 0.997 SS-vwcmt,qtz,occ wh cbt & glau,t brn cly,fac 9 40 10218.05 51.41 19.1 30.5 13.1 49.9 17.4 0.0 2.68 0.000 32.600 1.359 SS-vwcmt,qtz,occ wh cht & glau,t brn ch/ 9 41 10219.05 52.23 17.4 36.1 16.4 46.4 19.7 0.0 2.69 0.000 32.600 1.553 SS-vwcmt,qtz,occ wh cbt & glau,lr brn cty,frac 9 42 10220.00 3.58 14.2 31.2 21,0 53.5 10.2 0.0 2.73 0.000 32.600 0.638 SS-vwcmt,qtz,occ wh cht & glau,t brn cb/ 9 43 10221.05 47.92 17.7 33.9 15.9 45.6 18.0 0.0 2.68 0.000 32.600 1.519 SS-vwcmt,qtz,occ wh cbt & glau,t brn cly,frac 9 44 1022~.00 3.04 13.2 29.5 20.9 55.8 8.5 0.0 2.73 0.000 32.600 0.503 SS-vwcmt,qtz,occ wh cht& glau,wk brn cly lam 9 45 10222.95 1.49 12.4 32.2 25.0 57.3 7.2 0.0 2.71 0.000 32.600 0.433 SS-vwcmt,qtz,occ wh cht& glau,wk brn cly lam 9 46 10224.25 708.22 23.4 32.0 5.2 44.0 26.8 0.0 2.66 0.000 32.600 2.802 SS-vwcmt,qtz,wh cht,occ glau 9 47 10225.05 87.22 18.9 36,5 12.1 43.7 24.4 0.0 2.83 0.000 32.600 2.175 SS- vwcmt,qlz,wh cht,ooc glau 9 48 10226.05 1115.67 26.3 31.3 4.7 42.7 26.6 0.0 2.66 0.000 32.600 3.329 SS-vwcmt,qtz,wh cht,occ glau 9 49 10227.05 615.85 25.3 35.2 4.9 41.8 30.3 0.0 2.66 0.000 32.600 3.835 SS-vwcmt,qtz,wh cht,occ glau 9 50 10227.95 495.22 24.3 35.1 8.7 44.2 26.4 0.0 2.70 0.000 32.600 2.871 SS-vwcmt,qtz,wh cht,oo; glau 9 51 10229.05 222.21 23.5 30.2 10.5 46.3 19.7 0.0 2.82 0.000 32.600 2.073 SS-vwcmt,qtz,wh cht,occ glau I 9 52 10230.05 291.34 22.9 40.6 19.8 47.3 20.8 0.0 2.71 0.000 32.600 2.015 SS- vwcmt,qtz,wh cht,occ glau *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFERTO TEXT FOR DETAILS ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA CORE LABORATORIES FILE' BP-3-1486 23-MAR-93 ANALYSTS:PB,DS, FE,TR,DS DEAN STARK ANALYSIS PERMEAEI LITY POROSITY SATURATIONS Gl:IAI N MUD # # ..FT MD (%) .. .% PY...1 .... % Pv J . % Pr. J % I~...I . % Pv GM/CC PPM PPM % DESCRIPTION ..... 9 53 1 0231.05 241.94 22.3 37.4 14.8 48.8 22.8 0.0 2.70 0.000 32.600 2.143 SS-vwcmt,qlz,wh cht,occ glau 9 54 1 0232.25 248.51 22.8 33.1 12.3 48.2 20.9 0.0 2.72 0.000 32.600 1.841 SS-vwcmt,qtz,wh cht,ooc glau 9 55 10233.05 207.69 21.9 33.5 13.6 47.8 19.9 0.0 2.71 0.000 32.600 2.039 SS-vwcmt,qtz,wh cht,occ glau 9 56 10234.00 200.99 22.1 32.2 17.4 49.1 14.8 0.0 2.72 0.000 32.600 2.026 SS-vwcmt,qtz,wh cht, occ glau 9 57 10235.05 190.21 21.9 34.5 11.3 49.0 23.3 0.0 2.72 0.000 32.600 2.370 SS-vwcmt,qtz,wh cht, occ glau 9 58 10236.05 249.91 22.8 33.6 11.2 48.4 22.5 0.0 2.70 0.000 32.600 1.958 SS-vwcmt,qtz,wh cht,occ glau 9 59 1 0237.15 219,35 22.5 47.9 26.4 35.4 20.0 1.5 2.72 0.067 32.600 2.639 SS-vwcmt,qtz,wh cht, occ glau 9 60 1 0238.15 228.51 22.3 45.0 21.3 40.9 20.9 2.8 2.69 0.102 32.600 2.237 SS-vwcmt,qtz,wh cht, occ glau .......................... *-DENOTES SAMPLE WAS REMOVED BEFORE CLEANING WAS COMPLETED BECAUSE OF TIME CONSTRAINTS- REFER TO TEXT FOR DETAILS CORE SMPL # # CORE LABORATORIES ARCO ALASKA, INC. P1-20 Pt. MdNTYRE UNIT NORTH SLOPE, ALASKA LEAD SLEEVED OVERBURDEN DATA DEAN STARK ANALYSIS FILE: BP-3-1485 4-MAR-93 ANALYSTS:PB,DS, FE,TR,DS OVERBUR PERM POROSITY SATURATIONS GRAJN MUD , , , FT PSIG MD (%) % PvIj% Pv 1% PvI % Pv % Pv GM/CC PPM PPM % 9 10009.15 10 10010.00 11 1 0011.00 12 1OO12.OO 13 lo013.OO 14 10014.00 15 I O015.25 1 6 1 0016.25 16 10016.25 17 10017.10 18 1OO18.20 19 10019.00 21 1 0021.25 22 10022.10 27 1 O027.OO 32 10034.25 28 10027.85 DESCRIPTION 2581 340.24 23.3 28.1 24.9 58.5 0.0 3.1 2.89 0.095 29.750 ND 2581 3431.01 24.2 22.8 20.2 57.9 0.0 2.6 2.90 0.092 29.750 ND 2581 157.44 21.8 35.5 33,1 58.6 0.0 2.4 2.96 0.079 29.750 ND 2581 56.83 23.0 44.2 29.3 52.1 0.0 14.9 2.85 0.439 29.750 ND 2581 714.42 28.0 34.9 34.9 41.8 0.0 0.0 2.86 0.000 29.750 ND 2581 378.23 25.6 31.5 31.5 48.3 0.0 0.0 2.87 0.000 29.750 ND 2581 58.62 19.5 20.6 20.6 61.7 0.0 0.0 2.85 0.000 29.750 ND 2581 68.51 20.6 19,4 19.4 53.2 0.0 0.0 2.84 0.000 29.750 ND 2581 79.00 20.6 22.8 22.8 53.3 0.0 0.0 2.83 0.000 29.750 ND 2581 370.74 21.8 38.0 36.3 53,3 0.0 1.7 2.86 0.042 29.750 ND 2581 1 68.32 23.3 30.3 30.3 49.0 0.0 0.0 2.86 0.000 29.750 ND 2581 11.09 18.9 19,9 19.9 69.2 0.0 0.0 3.03 0.000 29.750 ND 2581 311.43 23.5 28.0 24.9 48.0 0.0 3.2 2.90 0.085 29.750 ND 2581 203.84 23.8 26.2 26.2 47.0 0.0 0.0 2.85 0.000 29.750 ND 2581 730.94 26.1 27.8 27.8 47.2 0.0 0.0 2.96 0.000 29.750 ND 2581 38.31 13.6 24.2 24.2 66.7 0.0 0.0 2.82 0.000 29.750 ND 2581 506.82 26.8 38.4 38.4 49.0 0.0 0.0 2.86 0.000 29.750 ND SS-p & v'~cmt, qtz,glau,wh cht, sid,frac SS- pcmt qtz, gtau,occ wh cht, brck en SS-p & vwcmt,qtz,glau,wh cht, sid,frac SS- pcmt, qtz,glu,wh cly filled & open frac SS- pcmt, qtz, gla u,wh chi frac SS-mod cmt,qtz,glau,wh chtbroken SS-vwcmt,qtz,glau,sid,wh cht,frac SS-wcmt,qtz,g~au,,occ wh cht SS-wcmt, qtz,gtau,,occ wh cht SS- pcmt, qtz, Cau,,wh cht,br ck en SS-vwcmt,qtz,glau,sid,t wh cht SS-vwcmt,qtz,glau,sid,t wh cht& brn cly,fac SS- wcmt,qtz,gtau,wh cht,broken SS-wcmt,qtz,gtau,occ wh cht SS-mod cmt,qtz,glau,occ wh cht SS- wcmt, qtz, gtau,sid,bm cly SS-pcmt~qtz,glau,occ bk cmt,t lim,broken SECTION 3 CONVENTIONAL CORE ANALYSIS STATISTICAL AND CORE GAMMA DATA .ompany 4ell ARCO ALASKA, INC. P1-20 CORE LABORATORIES Field : POINT MCINTYRE Formation : KUPARUK Fi 1 e No.: AR1485 Date : 24-FEB-g3 SUPI#A TABLE I RY OF CORE DATA ZONE AND CUTOFF DATA ZONE: Identification NOT SPECIFXED Top Depth --- 9655.0 ft Bottom Depth ............. 12050.0 ft Number of Samples 557 DATA TYPE: Porosity - (HELIUM) Permeability ....... (HORIZONTAL) Kair CUTOFFS: Porosity (Minimum) Porosity (Maximum) Permeability (Minimum) --- Permeability (Maximum) --- Water Saturation (Maximum) Oil Saturation (Minimum) - Grain Density (Minimum) -- Grain Density (Maximum) -- Lithology Excluded ........ 0.0% 100.0 % O. 0000 md 100000. md lO0.0 % O.O% 2. O0 gm/cc 3.70 gm/cc NONE CHARACTERISTICS REMAINING AFTER CUTOFFS ZONE: Number of Samples ..... Thickness Represented - POROSITY: Storage Capacity Arithmetic Average .... Minimum ............... Maximum ....... Median ................ Standard Deviation .... GRAIN DENSITY: Arithmetic Average .... Minimum ............... Maximum ............... Median ................ Standard Deviation .... 556 556.0 ft 10087.3 ~-ft 18.7 % 2.3% 31.2 % 19.1% ±5.4 % 2.97 gm/cc 2.66 gm/cc 3.66 gm/cc 2.94 gm/cc ±0.24 gm/cc PERMEABILITY: Flow Capacity ......... 70369.5 md-ft Arithmetic Average .... 138. md Geometric Average ..... 11.0 md Harmonic Average 0.39 md Minimum ..... 0.01 md Maximum ............... 2388. md Median ...... 22.5 md Standard Dev. (Geom) -- K.IO±1'282 md HETEROGENEITY [Permeability): Dykstra-Parsons Var. -- Lorenz Coefficient .... 0.975 0.726 AVERAGE SATURATIONS (Pore Volume): Oil ................... Water ................. 36.4 % 53.8 % Stat 1 - 1 SECTION 4 APPENDIX .--., _ ,t ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 25, 1992 Perry Brown Core Laboratories 8005 Schoon St. Anchorage,:AK 995~8 Dear Perry: Subject: Point McIntyre Core Analysis Procedures Poorly Consolidated Sample Handling Recently, poorly consolidated samples were encountered in P1-20 and P2-30. Tlmse plugs could not be taken in the fashion outlined in the procedures. Core analysis procedm'es for these plugs were assembled with the heIpof ]. Rathmell, John Dacy, yourself and myself. These procedures have been presented to the Point Mdntyre Equity Team petrophysicists and they concur with the methods. Preserved pieces will be packed in dry ice for a minimum of eight hours. Once frozen throughout, the piece will be stripped, cut if necessary and slabbed with liquid nitrogen. All plugs should be cut and mounted one at a time to prevent condensation. At any time in the process, if a plug begins to prematurely thaw, it should be refrozen. A one and one half inch plug will be drilled with liquid nitrogen. The end pieces will be trimmed with a dry saw. The plug will be weighed. A strip of Teflon tape, a strip of lead foil, two 120 mesh screens and two 60 mesh screens will be weighed. The piece will be wrapped with two layers of Teflon tape and then with the lead foil leaving a small amount of foil hanging over the edge of the plug. A I20 mesh and then a 60 mesh screen will be applied to each end. The Icad foil will be crimped to hold the screens in place. The plug will be preserved in saran and foil. The sample will be weighed and stored in dry ice. Once a load cell becomes available, a plug will be weighed. The saran and foil will be stripped and the plug will be placed in a hydrostatic cell. A sleeve pressure of 1000 psi will be applied to secure the mounting material. The plug will be thawed in the cell. Once thawed, the plug will be weighed. The plug will follow the original procedures from plug storage through drying. Perry Brown November 24, 1992 Page 2 Once the plug has a stable dry weight, the plug will be placed in a hydrostatic cell. An overburden pressure provided through tho operating company r<'t,rcsentative will be applied° The plug pore volume will be determined tl~rt)t~gh Boyles law with helium. While the plug is in the cell, the permeability xx, ill L~ measured. The sample will be removed from the cell. The plug's length ,-~t~tt diameter will be measured with a caliper. While carefully retaining all !',r'.:it~s, the mounting materials will be removed from the plug. With all the loose ~;rains, the grain volume will be determined through lloyles law with helium. l'();-osity can be determined through the equation: O= 100 Vp Vp + Vg wl~ere: Vp = Vg = O = Pore Volume at stress, cc Grain Volume, cc Stress Corrected Porosity, percent you have any questions, please call me at (907) 263-4749. Micl~ael S. Harr MSH:tg CC: K Dahlberg S. S. Lauver R. G. M. Oba J. D. Perrin G. K. Phillips J. J. Rathmell S. M. Renke K. I. Weiser G. S. Wylie Exxon ATO-480 ATO-420 BPX ATO-496 PRC-E1303 ATO-468 ATO-470 ATO-490 ]. M. Dacy Core Laboratories 10205 Westheimer Houston, TX 77042 1 I December 1992 Subject: Net Effective. Overburden Pressure Calculation for P 1-20 and P 2-30 From/Loc,~tion: ]. J. Rathmell - PRC-EI303 Telephone: 754-6382 To/Location: Mike Harr - ATO-462 This is to document the net effective overburden pressure colculation which we discussed with Exxon and BPX representatives in our teleconfer.,:nce, November 10, 1992. Net effective overburden pressure is needed for poorly consolidated intervals in wells P 1-20 and P 2-30. The porosity and permeability of core plugs from these intervals must be measured under overburden pressure. This is the standard procedure for poorly consolidated rocks which must be frozen in order to cut plugs. The calculationa] procedure I have used is outlined in Appendix 1. The values resulting from these calculations have been summarized in Table 1. I have depended upon Mike Harr to provide the data entries in columns B through I. The remaining entries in Table 1 are calculated with exception of fracture parting pressure which was provided by S.C. Weimer based on the Point McIntyre #9 step rate test. D.A. Fisher provided an estimate of permafrost thickness. T.J. Wightman provided a correlation of bottom hole pressure with mb,sea depth. These data are in their original ',. rm in Appendix 2. The calculation gives net effective overburden pressure as follows: WELL NET OVERBURDEN PRE,~IflRE P 1-20 2581 psig P 2-30 2560psig men~be used in the. laboratory measurements. Q .~e Rathmell JJR/dre cc.' T.]. Wightman D.A. Fisher S.C. Weimer S.M Renke A ttachmovLq AR3~--4~39 POINT MCINTYRE SERVICE COMPANY LABORATORY CONTRACTOR ON-SITE AND LABORATORY CORE ANALYSIS REQUIREMENTS August 3,1992 TABLE OF CONTENTS CORING OBJECTIVES ................................................................................................................... 1 GENERAL GUIDELINES ............................................................................................................... 1 WELL SITE CORE HANDLING AND SAMPLING ......................................................................... 2 Recommended Tools and Materials ..................................................................................... 2 Material and Site Preparation ........................................................................................... 3 Samples of Coring Mud for Tracer Analysis ......................................................................... 4 Inner Barrel Laydown, Cutting, Capping and Transportation ............................................... 4 Core Lay-Out in Trailer 1 ................................................................................................... 4 Quality Control Wells ....................................................................................................... 4 Core Handling Procedures ................................................................................................... 6 Core Preservation ............................................................................................................... 7 Core and Mud Sample Transportation to Anchorage ............................................................. 8 ROUTINE CORE ANALYSIS ......................................................................................................... 8 General Core Handling ....................................................................................................... 8 Mud Filtrate Samples ........................................................................................................ 9 Surface Core Gamma Log .................................................................................................... 10 Cutting and Trimming Core Plugs ........................................................................................ 10 Routine Horizontal Core Plugs ............................................................................................ 11 Quality Control Well ............................................................................................. 11 All Other Cores ..................................................................................................... 12 Dean Stark Analysis .......................................................................................................... 12 Timing ............................................................................................................................... 13 Porosity ............................................................................................................................. 14 Grain Volume ......................................................................................................... 14 Bulk Volume .......................................................................................................... 14 Correction for Grain Loss ......................................................................................... 14 Permeability to Air ............................................................................................................ 15 Tracer Analysis .................................................................................................................. 15 Core Slabbing ..................................................................................................................... 15 Future Uses of the Preserved Core ....................................................................................... 16 Appendixes .................................................................................................................................... 19 Tracer Analysis In Drilling Fluids, Core Extracts ................................................................. 20 Scope .................................................................................................................... .20 Instrumentation--Hardware ................................................................................. .20 Reagents ............................................................................................................... .20 GC---Conditions .................................................................................................... .21 Analytical Procedure ............................................................................................. 21 Calculation of Filtrate Saturation and Plugging Fluid Saturation ........................................ 23 Flow Charts ............ · ................................................................................................. : ......... 26 CORING OBJECTIVES August 3, 1992 The coring involves mineral oil base cores in 4-13 wells. These cores will provide in-situ water saturation, rock properties and lithology for the use of the Point Mclntyre Working Interest Owners. GENERAL GUIDELINES 1. This procedure is for well site sampling and laboratory core analysis. . e Core Laboratories must be able to mark, lay-out, cut core barrels and preserve on-site. They must be able to plug on-site. Laboratory sampling and routine core analysis will be conducted in Anchorage. Tracer will be conducted elsewhere. Early cored wells might require plugging on-site while other wells may not require plugging on- site. Earlier wells are more likely to have extensive well site sampling. All wells will involve the following: A. Core preservation (Saran wrap and aluminum foil on-site). B. Core Diameter - 4-inches C. Inner Barrels - Aluminum, 30-foot, 60-foot D. Low invasion core bits and coring procedures E. Expedited core processing Timing will be between March 1, 1992 to March 1, 1993. Estimated well site timing and estimated volume could vary significantly depending on rig schedules and data requirement needs. The first well may begin coring April 21, 1992. Other wells will follow in one-month intervals until a second rig becomes available later in 1992. Two well coring operations might occur at the same time dependant on rig schedule. WELL ESTIMATED AMOUNT OF CORING A-1 605 MD FT -' B- 1 250 MD FT C-1 160 MD FT D-1 310 MD FT m E-I 150 MD FT A-2 150 MD FT B-2 220 MD FT C-2 160 MD FT D-2 50 MD FT E-2 130 MD FT F-2 211 MD FT ~' G-2 322 MD FT H-2 400 MD FT . (Actual 261 ft., cored May, 1992) Core Laboratories should have more materials/supplies on-site than might be initially estimated from estimated footage of coring due to the preservation of many small pieces. Well site personnel requirements per job will vary from 8-24. Personnel number requirements will vary depending on whether plugging is conducted on-site. Core Labs will provide 2-16 people per well depending on well site activities. Laboratory staffing and equipment must be adequate to meet core analysis timing requirements. 9, 10. August 3, 1992 Materials that Core Labs must be able to supply on coring jobs are listed below. Quantities will vary depending on amount of projected coring for each individual well. The procedures outlined in this contract proposal may vary significantly from well to well. ARCO will provide details of revisions prior to conducting the work. Iodonapthalene drilling mud tracer will be used in all wells to quantify filtrate invasion. WELL SITE CORE HANDLING AND SAMPLING Recommended Tools and Materials Quantities will vary depending on amount of projected individual well cored interval. (* = supplies needed only for on-site plugging) Aluminum foil Bailing wire Bottles for routine plugs (500) must hold I 1/2" x l 1/2" routine plug or I endpiece approximately 1 1/2" x 1 1/4" after Saran wrap and foil* Bottle sealing tape* Bubble wrap Cold weather clothing Containers for mineral oil, 10 gallon, 3t30 psi pressure limit (4)* Copper tubing, fittings, and valves for mineral oil (for 2 drills)* Core boxes (quantity varies from well to well) Core drills for routine plugs, with '1.5" diameter core bits (2)* Core Seal, :i lb/foot of core Coveralls for personnel Cut-off saw motor (spare, depending on preapproved rental charges) Cut-off saw spare blades (2, depending on preapproved rental charges) Cut-off saw with vacuum for dust collection (depending on preapproved rental charges) Drill press motor (spare)* Dust masks for personnel ~ Ear plugs Face shield for use during rock saw work Glass strapping tape .z- Gloves, cloth ? Gloves, rubber Hard hats/safety glasses -~' Heat Sealer for Protec Core Hexadecane for cutting plugs, 70 gal* Ice chests and blue ice to ship samples to Anchorage (8 large)* / Labels, white stick-on, for core depth (400)* ~, Large chisel Lumber crayons, white and yellow (2 dozen each) Markers, waterproof, black and red (2 dozen each) ':.'. Metal bucket Nitrogen regulators(2)* Note pads and pens/pencils Nutdriver '~/Plastic bottle for cleaning ruler ~ Plastic sample bags, large (1000), small (1000) 'Pliers \ Pump and base for core drill* ~ Refrigerator for sample storage at well site* ~ Rock hammer "Safety boots and glasses for personnel '~ Sample bags for state chips ~,, Saran wrap ~' Screw driver (rechargeable) i'~ Screw drivers and nut drivers ~" Stapler X Strapping tape Tape gun (3) Tape measure (100 ft) · · Thermometer for Core Seal, metal dial type Trim saw for rout/ne plugs, I 1/2" long* '~ Trim saw motor (spare)* '~ Trim saw spare blades (2)* i)d Visc/uene Wire Wire cutters (2) ~ Wood block spacers (300) Wood rulers (3) Zip Lock bags, large (50)/small (50) Flow Chart of Wellsite Operations A flow chart of wellsite operations is attached. Material and Site Preparation Upon arrivaI at the well site, the required preservation materials will be set up in the core trailer by Core Lab personnel.. The melting pot will be filled with Core Seal and turned on. The pot temperature will be adjusted according to the length of time before the core is recovered, place on low (180 °F) if more than 48 hours is anticipated. It is recommended that the melting pot be checked at regular intervals when turned on and never exceed the recommended dipping temperature for Core Seal (320 o. 330 °F). The dip pot temperature must be monitored and recorded for each core preserved. All personnel will be H2S certified and will need to familiarize themselves with the areas on the well site that they will be working in while retriev/ng the core such as the rig floor, pipe shed, and core trailer location. Contractor will prov/de safety equipment for their own Personnel. This includes, but will not be limited to, steel toed boots, safety glasses, hard hats, dust masks, etc. Also, all personnel should be aware of their areas of responsibility in the Preservation operation. · Two coring trailers will be required for wells with on-site plugging. ARCO will provide trailers. Trailer I w/Il be used for core layout, depth marking, sampling and Preservation of whole core. Trailer 2 will be used for core plugging and represervat/on of plug and endpiece. Routine core plugs cut at the well site will be Preserved in Trailer 2. One trailer will be required if all plugging is done in Anchorage. The trailer will be used for core layout, depth marking, sampling and preserving of whole core. Upon completion of the above PreParations, the core boxes should be put together and marked with dlent name, well name, core number, and box number. August 3, 1992 Samples of Coring Mud for Tracer Analysis August 3,1992 At the start and end of each core, the mud man will collect a mud sample from the suction pit. This sample will be 1 gallon, collected in a metal DOT approved container with screw cap and fiber lid seal. The label on the can will include well name, core number, core depth and date. This mud sample will be shipped with the core when it is sent to Anchorage. Inner Barrel Laydown, Cutting, Capping and Transportation The aluminum inner barrel will be laid down in 30-foot lengths on the skate and transported to the catwalk. Use a sling and hoist to carry the inner barrel to the inner barrel cutting cradle and cut it up. Wipe down the outer surface of the inner barrel to remove mud. Locate the top of the core and mark inner barrel. Double stripe red and black, red on right looking up-hole. Mark depths each foot on outer barrel starting from core top. Using pipe cutters, cut the inner barrel into 3-foot lengths. Place rubber caps on each end of core. Secure caps with hose clamps tightened by an air driven nut driver. Load inner barrel sections on fork lift and transport to core trailer for layout. Core Lay-Out in Trailer 1 The core should be laid out on the counter in 5- or 10-foot lengths by a Service Company Lab representative. Core barrel is layed on bench with red marking nearest the core trailer wall. Dump core out of inner barrel sections onto lay-out bench. Uphole is always to the left. Core pieces are wiped with dry rags to remove mud, fitted together, oriented with the apparent up dip at the top, depth marked and double striped for orientation. Depths shall be marked below the corresponding foot line and orientation lines marked with white on the right and yellow on the left using waterproof markers. It is recommended that lumber crayons be used for marking core surface and Marks-A-Lot markers (red and black, red on right) for foil wrapped core. · - While the core is laid out, routine analysis samples (3" X 4") are marked every foot starting at the foot marker and extending three inches below the marker. If this location is nOt suitable for plugging, the sample top may be moved down by 2.4 inches below the foot marker or the sample top may be moved 2.4 inches above the foot marker. These samples are identified with the initials SCF (Service Company, Field Sample) and must be dry sawed to separate them from the core. At 90° clockwise from the white and yellow double stripe while looking up hole, mark the plug location with a circle as close to the foot marker as possible. The SCF whole core samples are preserved separately from the remaining core for ready identification once they reach Anchorage. Slabbing on-site will be done only when plugs are taken on-site. While core is marked, core inventory and descriptions can be performed providing the exposure of the core is kept to a minimum. State chips will be taken in Anchorage. Quality Control Wells Overview of Approach Well site core sampling is planned for quality control purposes. This type of sampling might be more intense in the early wells and may decrease in later wells if it is shown that sampling in Anchorage provides similar water saturation and tracer distribution to that obtainable in the field. It is also possible that all wells may be sampled at the wellsite. This decision will be made after two wells are cored. Below ~or the . . . . are the procedures which are planned for the quality control wells. These procedures will apply first two wells: Conduct coring in the usual manner in order to achieve low invasion. Core bits appropriate to the rock type will be selected for coring. Mud tracer, iodonapthelene, will be used to indicate the level of invasion by the mud filtrate. The core handling for these cores will be the similar to all other cores as specified under Core Handling Procedures detailed below. When the core is laid out and marked at the well site, dry saw a 3-inch full diameter section of core every foot for routine analysis. Mark it with the initials SCF. Immediately preserve all core, including the dry sawed sections, in Saran wrap and aluminum foil as described later in more detail. Mark the location of the SCL (Service Company, Laboratory Samples) section (2-inch full diameter; once every third foot) on the foil for ready identification in Anchorage, This. two-inch section will be cut in Anchorage. Proceed with normal core preservation for all samples except the dry sawed 3-inch sections. Routine horizontal core plugs will be cut at the well site from the SCF samples in each foot. These core plugs will be 1.5-inch diameter cut parallel to bedding planes completely through the core after a l-inch slab has been removed from the face where the plugging bit enters. This will prevent driving tracer into the' core center if the core plugging fluid invades the core. The routine plug will be trimmed and preserved as discussed below. Double stripe the 1-inch slab for orientation. The remnant core/slab will then be represerved in Saran wrap and foil. Additional routine core sampling later in Anchorage can provide quality control on core preservation and tracer diffusion. Once in Anchorage, identify SCL sections as marked at the well site every third foot. Routine core plugs are cut from these sections immediately after the core arrives. Cut the two-inch section. These core plugs will be 1.5-inch diameter and cut parallel to bedding~ planes completely through the core after a 1-inch slab has been removed from the face where the plugging bit enters. Double stripe the 1-inch slab for orientation. The remnant core/slab will then be wrapped together in Saran wrap. The routine plug will be trimmed and preserved as discussed below. This sample will be analyzed for water saturation and tracer content for comparison to the well site samples. The first priority in data collection is to obtain porosity and water saturation in those intervals sampled both in the field and laboratory. Adjacent SCF and SCL plugs will be analyzed immediately. The .endpieces of both field and laboratory samples will be analyzed for tracer every six feet-of core in both field and laboratory samples. More tracer data can be obtained later as needed. If there is no well site sampling, then the above section entitled Quality Control .Wells can be ignored. A three-inch SC section will be identified for each foot, dry sawed from the core and preserved at the well site. This sample will be marked clearly SC, with the depth and with dOuble stripe orientation. At 90° degrees clockwise from the white and yellow double stripe while looking up hole, mark the plug location with a circle. If the section is unsuitable for plugging, the SC sample top may be moved down 2.4 inches below the foot marker or 2.4 inches above the foot marker. If the plugs-are cut in Anchorage, then the SC sample will be slabbed in Anchorage prior to plugging. The section would be replaced in sequence with the rest of the core, preserved and shipped to Anchorage for plugging. It is also possible all routine core plugs may be cut at the well site in all wells. This will be decided after the first two wells are cored. If plugging is continued on site, no plugs will be cut in Anchorage. August 3, 1992 Core Handling Procedures Core lay-out will proceed as described under Core Lay-out in Trailer 1 procedures. SCF samples are identified and the core is marked. SCF samples will be taken every foot. Whole core sections for SCF samples are dry cut on the rock saw to separate them from the core. The sawing operation requires a dust mask. A 1-inch slab is then cut at 90© clockwise looking up hole to the double mark. The double stripe is always on the most updip side of the core. This slabbed face will be the side where plugging starts. The circle indicating the plug location should always be on the one- inch slab. ROUTINE CORE SAMPLE SLABBED 1.5" X 1.5" PLUG Please note: If plugs are not cut at the well site, then the SC samples will not be slabbed at the well site. This face is immediately covered with Saran wrap and the 1-inch slab is placed on top so the Saran separates slab and butt portions. The 1-inch slab should be double striped for orientation. This section is then replaced in the core at the appropriate depth. The samples removed are replaced with wood block spacers containing the appropriate depth and sample marking. These samples are then wrapped in their normal depth sequence in heavy duty impermeable Saran (6 layers) and heavy duty aluminum foil (3 layers). SCF samples from every foot are taken to Trailer 2 for on-site plugging. Place a wooden block to hold the sample space until it returns from Trailer 2. Depth orientation lines are to appear on both the core itself and foil wrapping. A routine core plug will be cut at the well site from each foot of core; therefore, two core plugging devices are needed. A 1.5-inch horizontal core plug will be cut parallel to bedding completely through the whole core section at its center starting at the saw-cut face from which the slab was taken. Care should be taken to ensure the core drill is perpendicular to the slab face. Use hexadecane driven by nitrogen from a 10-gallon, 300 psi container. The SCF or SCL plug will always be cut as close to the foot marker as possible. If the sample is below the foot marker, plug at the top of the sample. If the plug is above the foot marker, plug at the bottom of the sample. Dab core plug, if necesary, with an Oilsorbent tissue to remove excess oil immediately after plugging. Use a fresh tissue for each plug to avoid tracer August 3, 1992 contamination. Trim one end of the core plug with a dry saw so the final plug is 1.5 inches long. If the plugging bit was not perpendicular to the slab face, first trim the slab side of the plug 1/8 inch (the width of the saw blade) and then trim off the endpiece so that the resulting plug is 1.5 inches long. The diagram below shows the trimmed plug. SC SAMPLE 1.25" 'END PIECE ROUTINE lCORE PLUG · . --irl The plug is passed on for preservation immediately in Saran wrap (6 layers), aluminum foil (3 layers), weighed and sealed in a labeled glass bottle with a teflon-lined plastic lid and sealing tape. Bottle label should spedfy well, core number, depth, and preserved plug weight. These plugs will be kept cold. in a refrigerator or on ice until analyzedin Anchorage. These plugs will be used for routine saturation measurement. The plug endpiece will be preserved immediately and separately from the plug as it is generated. The- endpiece must be marked with depth on the rock, identified as an endpiece (SCFEP) and wrapped with Saran wrap (6 layers) and aluminum foil (3 layers) and weighed (± 0.01 g). The endpiece from each plug is then placed in a glass bottle, sealed and taped. The endpieces will be kept cold in a refrigerator or on ice until analyzed for tracer content as specified in Table 2 in Anchorage. Bottle label should specify well, core number, SCFEP depth, tare and total weight. The routine core sample 3/4 remnant could be used to obtain a vertical core plug later on. This sample and the slab will be Saran and aluminum foil wrapped as one piece, depth marked and identified SCF in Trailer 2. The 1-inch slab should be double striped for .orientation. The sample and the slab are then returned to Trailer 1 for Core Seal coating and placed in depth sequence with the.rest of the core. Remove the wooden block when the sample is replaced in depth sequence. If geological samples are needed and the plug endpiece is still preserved, the slab may be used to obtain geological samples for thin sections, etc. The plug itself will not be used for geological sampling since it must be saved for possible future remeasurement of permeability or porosity as a part of quality control procedures. Core Preservation The core is placed with the top to the left on the bench in Trailer 1. This will help insure that the proper core orientation is maintained. When moved across to the other bench for wrapping this orientation is maintained. The wrapping stations must be covered with Oilsorbent tissue to provide a soft surface which will not damage Saran and foil. Wrapping should begin as soon as possible following SC sample identification and separation. The core . . August 3, 1992 is then wrapped with Saran wrap (6 layers), then wrapped with aluminum foil (3 layers) and marked. Wrapped core will be marked with depth using a black Marks-A-Lot and with red and black (red on right) orientation lines. Glass strapping tape is placed on the foil under the wire to prevent puncture of the foil. Wire is wrapped tightly around the center of the core to facilitate the dipping of the samples in Core Seal. The core should be completely submerged in the dip tank for 1-2 seconds and then hung on the cooling rack. After the Core Seal has cooled (3-5 minutes), the sample should be redipped to insure a proper seal and to help protect the core from damage during shipment. After the second dip, the wire is cut at a point just above the preserved piece and a small amount of Core Seal should be placed over the exposed wire to eliminate a wicking effect. As the core is preserved, the core is then placed in oil absorbent tissue or bubble wrap lined core boxes. Then, the core is checked for proper preservation and markings. Occasionally the Core Seal will be too thick to read the markings. Therefore, if-possible, a waterproof marker should be used to mark the appropriate designations on the outside of the sample. The core is placed in the core boxes and the boxes are labeled on the outside with well name, equity well name core number and box number. Then, the boxes are sealed. A well site inventory shall be completed for each core and the boxes are placed in shipping crates. Core and Mud Sample Transportation to Anchorage Tracer analysis data will be most valid immediately after coring as an indicator of invasion and degrades with time due to diffusion. The transportation of the cores and associated mud samples will be expedited. Immediately upon completing the boxing of the preserved core, the core, mud samples, routine core plugs and endpieces will be transported by airplane to Anchorage. Ice chests and blue ice will be used to transport routine core plugs and endpieces to Anchorage. Place the jars in holes cut in styrofoam to prevent:breakage in the ice chests. The service company personnel will meet the flight and pick up the core. Core processing will begin immediately upon arrival at the laboratory. ROUTINE CORE ANALYSIS There will be a designated representative of the Operating Company who will act as the point of contact for all matters relating to routine core analysis. All communications with the Service Company will be through that point of contact. The point of contact will also be notified if other Working Interest Owners wish to observe ongoing analysis operations. The operating company will provide a list of personnel who have access to the slabbed core. General Core Handling Core sampling will be conducted with minimum elapsed time since the core was cut and preserved. Tracer diffusion stops once routine plugs are isolated from the more invaded outer part of the core. Sample the core immediately upon arrival at the service laboratory regardless of the time of day. The service company personnel will be notified when the core leaves Prudhoe Bay and will pick-up the core shipment at the airport once the freight company releases it. The service company can expect to receive up to two 60-foot cores in a single 24-hour period. In straighter holes and good sandstone pay, it may be possible to cut as many as three cores a day. The primary objective is to obtain true connate water saturations with consistent analytical techniques. Laboratory procedures and core handling should always be done consistently. Exposure to air should be minimized to avoid evaporation of fluids and wettability changes. August 3f 1992 A tracer will be used to identify those routine core plugs that have significant mud filtrate invasion. The tracer chemical is iodonaphthalene which is analyzed chromatographically with an electron capture detector. It will be found in the flask with the toluene and extracted crude after Dean Stark analysis. LVT-200, the base oil of the mud, can be used as a back-up tracer. Care should be taken to ensure that there is no inadvertent contamination with other chlorinated hydrocarbons, such as chloroform, which will be used in core cleaning. The analysis procedure used to detect the tracer is extremely sensitive with detection limits of 50 ppb. Large concentrations of chloroform may obscure the tracer which is expected to be present in the Dean Stark toluene at less than 1 ppm. Chlorinated solvents must never be used to clean glassware or core drill equipment. Glassware used for chloroform-methanol cleaning must never be used for the Dean Stark. Each new container of toluene must be sampled and analyzed prior to its use. . The quality control cores are needed to ensure water saturation and tracer distribution are the same in the laboratory as they were at the well site. Well site routine core plugs will be taken once per foot in at least the first two wells. In these wells, a routine horizontal plug and an endpiece will also be cut once every three feet later in the Anchorage lab. These contiguous samples will be analyzed for tracer concentration, porosity and water saturation. Some endpieces will also be analyzed for water saturation and tracer to provide inside and outside sample data. Tables 1 and 2 identify sample types, sample and data frequency. . All plug drilling will be done with hexadecane. The containers of hexadecane must be sampled at the time they are opened for use. These samples will be sent to the outside laboratory with the toluene before use to analyze for materials which may give a response on the electron capture detector. A record will be kept by Core Laboratories concerning the well core and plug numbers cut with a given container of hexadecane. . Sawing will be done with a dry saw for small samples such as plugs or when cutting out full diameter core sections. Slabbing can be conducted with cooled nitrogen gas to cool the saw blade. Slabbing will only be done after sampling for saturation measurement is finished so the small amount of contamination from condensed moisture which may occur here should not be a problem for any additional tests. o All core will be 1/4 slabbed at a later time. The core will be kept in a preserved state until it is slabbed. Any samples which are depreserved for the purpose of sampling and analysis will be represerved as quickly as possible to prevent loss of fluids from the remnant. After slabbing, the 3/4 butt end will be immediately represerved with minimum exposure. The 1/4 slab will become a library sample and should be double striped and placed in a slab box. . Chips will be taken for the State of Alaska at the time of core plugging, if not already taken at the well site. 10.¸ Calibrations will be performed on all balances using standard weights at least once before every core. Weights used should approximate sample weights. Flow Chart of Laboratory Operations A flow chart of laboratory operations is attached. Mud Filtrate Samples There will be two drilling mud samples shipped from the field with each of the cores. One of these will be taken at the start of coring and one will be taken at the end of coring. A sample of the filtrate is needed so that the tracer concentration can be analyzed. This tracer concentration in the filtrate is August 3,1992 essential to the calculation of filtrate concentration in the cores. Therefore, it must be collected and sent with the toluene samples from a given core in order to obtain the filtrate concentration. M.I. Drilling Fluids is providing a high pressure, high temperature filter press to filter these mud samples. Core Laboratories will filter the samples. The filter press should be cleaned with naphtha and dried at 300 °F between samples. Conduct the filtration at 500 psi and 150 °F until 2 cc of filtrate are collected. This will take about 1 hour. Collect filtrate in a 5-10 cc glass container; seal and tape when finished. Identify core number, core depth, well name, and date on the label. Surface Core Gamma Log The core is laid out on tables in depth order. The core remains preserved while it is gamma logged. The core gamma unit is calibrated with a 200 APl gamma ray emitter before every core. The core is placed on a conveyor belt (beginning with the bottom of the core) which moves the core at a constant speed under the gamma detector. The pieces are butted tight to one another, with no breaks in measurements, until the core is completely logged. Now the recorded gamma ray response is digitized and plotted. Cuffing and Trimming Core Plugs Core plugs will be cut with hexadecane. New containers of the oils should be analyzed chromatographically before use so that inadvertent interference with tracer analysis does not occur. If LVT-200 is needed as a tracer, the hexadecane will not interfere with its analysis. To ensure there is no contamination with tracer from previous plugging operations, the oil will be driven with regulated nitrogen from a/O-gallon container. The hexadecane will be used only once. Cut the 1.5-inch diameter horizontal routine plugs parallel to bedding plane. Look for yellow and white double stripe on top of the core, rotate core 90" clockwise while looking up hole and dry saw a 1- inch slab from the whole core. Double stripe the 1-inch slab. The plug will be cut from the butt portion starting at this saw-cut face. The diagram below illustrates the slab and plug locations. ROUTINE CORE SAMPLE SLABBED FAC 10 August 3, 1992 Note: This diagram will apply to any plug cut in Anchorage or at the well site. However, the SCL samples are two inches in length instead of three inches. If core plugs are not cut at the well site, the three inch section, cut with a dry saw at the well site, will be used in the laboratory for plugging. A circle will indicate the direction for the cutting the core plug. The plug will always be cut as close as possible to the foot marker as possible. If plugs are not cut at the well site, then slabbing before plugging will be done in Anchorage· The plug should be cut completely through the center of the core and as close to the depth mark as possible. Take care to be sure the plugging bit is perpendicular to the slab face, otherwise the plug may need to be trimmed. Dab core plug, if necesary, with an OilSorbent tissue to remove excess oil immediately after plugging· · Trim one end of the core plug with a dry saw so that the final plug is !.5 inches long. If the plugging bit was not perpendicular to the slab face, first trim the slab side of the plug 1/8 inch (the width of the saw blade) and then trim off the endpiece so that the resulting plug is !.5 inches 'long. Identify well and plug number on the core plug and endpiece. Preserve plug and endpiece separately in Saran wrap (6 layers) and aluminum foil (3 layers). Take preserved weight of the plug or end piece. Relabel with plug/EP number on the foil. Place wrapped plug and endpiece in separate bottles, seal and tape. Label the bottles with well name, depth, plug number and total weight. Indicate endpiece with EP following plug number. Store the plug and endpiece at 50 °F in refrigerator. The figure below shows the plug and trimmed end. SC 'SAMPLE Routine Horizontal Core Plugs Ouality Control Well -- If the core is from a quality control well, a routine horizontal core plug and endpiece 1.5 inches in diameter are c"ut, one per three feet, in the lab immediately below the field sample location in that foot. The SCL section should have been identified and marked at the well site. Depreserve the appropriate whole core sample and cut the 2-inch whole core section with a dry saw. A l-inch slab is , . August 3, 1992 cut 90© clockwise looking up hole to the double mark. The 1-inch slab is double striped for orientation. All routine horizontal plugs and end pieces must be cut as rapidly as possible and plugging should be completed within 24 hours after the core reaches the surface at the well site. Weigh the plug or end piece, and preservation materials. Preserve the whole core sample in Saran wrap and aluminum foil before it is moved to core plugging. Place Saran wrap between slab and butt portion; then, wrap them together. The cutting of the Anchorage core plug and endpiece in a quality control well will be exactly as described above except that a 2-inch long core segment is used rather than a 3-inch long whole core segment. The core plug is cut through the center of the 2-inch core segment. No vertical core plugs will ever be needed from these samples. Routine core plugs will also be cut at the well site in quality control wells. These will be transported from Prudhoe Bay in ice chests with blue ice to maintain Iow temperature and prevent loss of water from the plug. Routine core plugs cut at the well site will be taken immediately to the Dean Stark station for analysis. If a Dean Stark apparatus is not available, the plugs should be maintained at 50 °F until analysis can be performed. Both wellsite and Anchorage lab routine core plug endpieces will be analyzed once every 6 feet in quality control wells. Endpiece analysis will always be done on immediately adjacent samples from the wellsite and the Anchorage lab. The analysis procedure for the endpiece will be the same as for routine core plugs except air permeability will not be determined. All Other Cores If the well is not designated quality control, the routine core plugs will be cut once every foot. Whole core samples for routine analysis have been dry-sawed each foot from the core and preserved separately at the ~well. If core plugs are taken at the well site then none will be taken in Anchorage. Immediately after completing the core gamma, separate SC sections. Depreserve these samples one at a time and cut a 1.5-inch diameter routine horizontal plug as close to the upper end of the sample as possible. The technique for plugging, trimming and preserving this plug and endpiece has been described above. Routine core plugs will be analyzed one per foot. Core plug endpieces will be analyzed one per 6 feet. All routine horizontal plugs and endpieces must be cut as rapidly as possible and plugging should be completed within 24 hours after the core reaches the surface at the well site. Mark depth, orientation, and represerve the 3/4 whole core remnant in Saran wrap (6 layers), aluminum foil (3 layers) and Core Seal (two coats). The 3/4 remnant could possibly be used for cutting a vertical plug later on. Replace the preserved sample and the slab in depth sequence in the core. When plugs are cut in Anchorage, there will be no need to preserve the 1-inch slab taken prior to plugging. This was done in the field to avoid lost identification and breakage of the slab during shipping. Later, this routine sample slab can be placed in depth sequence with the rest of the slab, when slabbing of the Dean Stark Analysis Weigh the preserved core plug or endpiece after removing form the bottle and record this weight on the data sheet. This weight will be compared to the well site weight or the earlier Anchorage weight. Filtrate saturation in the core plug as indicated by a tracer will be used for quality control of water saturation. Anchorage plu$~ should be preserved in saran and aluminum foil, and weighed immediately after cutting. The plug should then be refrigerated until Dean-Stark analysis. Prior to loading, plugs should be reweighed to ensure preservation was adequate. 12 August 3, 1992 The Dean Stark method is used to determine water saturation. The tracer in the core will be removed in the Dean Stark extraction and will be found in the flask with the toluene, filtrate, hexadecane plugging oil and crude oil. Fresh commercial grade toluene must be used for each plug analyzed. New containers of toluene must be sampled and analyzed before use. The flasks and glassware must be cleaned from the previous use to insure there is no residual water or tracer. Rinse condenser, core chamber and flask five times with 20cc of fresh toluene and discard the rinses. Weigh a clean, dry Dean Stark flask. Measure 100cc (+ 1 cc) of preboiled toluene and add to a preweighed flask. Toluene must be preboiled external to the glassware and within two days before use. To keep toluene loss to a minimum, keep the system closed except when adding or removing sample. The same person should always assemble the glassware. The core plug is removed from its preservation materials. The core plug is weighed to an accuracy of _+0.001 g, placed'in a predried and prelabeled cloth core bag to trap lost grains and reweighed to the same precision. If core plugs are soft or. poorly consolidated in some intervals, then encase them in Teflon tape, aluminum or lead foil and screens prior to the last weight. Obtain individual weights on Teflon, foil, and screens. The plug is then loaded into the Dean Stark apparatus without further delay. Then, seal the apparatus. Perform all tasks for one plug at a time. Toluene is refluxed until no further change in the water volume in the receiver is observed for four hours. Minimum extraction time is twelve hours. Use a wire or a wire with a teflon swab to scrape off water droplets from the neck of the condenser so they fall into the receiver. Do not use soap. Record the volume of the water to within _-ff).025cc (1.2% PV @ 10% porosity). If water volume is less than 0.5 cc, pull water from receiver with a syringe and weigh it. Remove plug from bag. Place the plug on top of the bag in a pre-dried, pre-labeled and pre-weighed thimble. Remove the flask and its contents from the Dean Stark. Remove toluene in the side arm with a syringe and add it to the flask. Weigh the flask + toluene mixture. Using a funnel that has been rinsed five times in toluene, pour flask contents into a D.O.T. approved shipping bottle. Be sure the cap is tightly closed so it will not loosen in shipping. In addition, seal the bottle with tape. Label bottle with well, core number, core depth and plug number (with SCF or SCL, and EP designation, if endpiece). These samples will then be shipped in one core lots (approximately 60 feet) to ARCO Exploration and Production Technology in Plano, Texas. The address can be found in the appendix. The packaging will be according to DOT regulations. The plug, bag and thimble should then be placed in a second piece of Dean Stark glassware for 87 vol% chloroform-13 vol% methanol azeotrope extraction. The chloroform will interfere with tracer analysis, if it should be present in the toluene extract in high concentration. Glassware used for azeotrope extraction should never be interchanged with glassware used for the Dean Stark. Change azeotrope after the first forty-eight hours; then, change it every twenty-four hours. Continue azeotrope extraction until clean azeotrope shows no crude oil color after eight hours. Streaming fluorescence with methylene chloride will be checked to monitor cleaning progress. Extraction time should be a minimum of two days. Dry core plug, bag and thimble in a convection oven at 180 F for 4 hours. Then, dry the core plug, bag and thimble in a vacuum oven for at least 24 hours at 180 °F and then to constant weight, _+0.01 grams, after four hours additional drying. Cool the plug, bag and thimble over desiccant. Weigh the plug, bag and thimble within _+0.001 g. Remove plug from thimble. Brush plug to remove fines and weigh again. Timing Glassware requirements should be based on two 60-foot cores per day with a 12-hour Dean Stark cycle and a 48- to 96-hour cleaning cycle. This means we need at least 80 sets of Dean Stark equipment for water measurement. The additional 20 sets will be required for the quality control cores. With these 80 13 August 3, 1992 sets of water determination equipment, 80 plugs could be generated for cleaning per day. Since the probable cycle time for cleaning is 2 to 4 days, we need 320 sets of equipment for chloroform-methanol extraction. The timing for cleaning is hardest to predict, since low permeability plugs will undoubtedly require more time. 400 separate pieces of Dean Stark glassware are required. This will permit a completion time for Dean Stark and cleaning of approximately 7 to 9 days for a 4 core well. The tracer analysis lab will finish up in about 9 days, or I to 3 days later, allowing 1 day shipping time to receive the first batch of samples. The tracer analysis time might be cut to 5 days with two chromatographs. Porosities should be complete about two days after the last samples are clean. Data processing time for saturations and tracer data is estimated as three days. The four core, well cycle time for water saturation, porosity, and tracer should be 14 days. Air permeability will probably lag water saturation, porosity and tracer data by about 5 days. In normal operations (one well drilled, cased and cored), all data on a given well could be complete before coring operations begin on the next well, assuming 20 days to drill and caSe, 5 days to core, 2 days to log, I day to skid the rig. For wells that require more than 4 cores, the time for completion of analyses will then be extended proportionately. For wells with fewer cores, there will be more flexibility on timing but these 'should be complete in the same time frame. Table 2 also indicates timing for data turnaround. Additional equipment will be required when two rigs are coring. Core Laboratories will provide an estimate of man power and equipment requirements for two rigs. Porosity Porosity is calculated from the difference in bulk volume and grain volume divided by the bulk volume. The pore volume is the difference between bulk volume and grain volume. That is the value used to calculate saturations. Grain Volume The helium porosimeter will be used to determine the grain volume of all samples. Plugs from drying are kept over desiccant until ready for grain volume measurement. If the plugs are exposed to laboratory air for more than 30 minutes, they should be redried and reweighed. The helium porosimeter should be recalibrated to _+0.1% twice a day. The porosimeter should be checked with a steel cylinder with a known volume to _+0.1% after every five samples and after a break in instrument usage of greater than one hour. If drift between successive calibrations will cause grain density to vary _+0.005 g/cc, calibrate before every plug. Bulk Volume Bulk volume for all 1.5-inch diameter plugs will be measured using the mercury porosimeter. Bulk volume will be measured within _+0.01 cc (_+0.05% BV). Maximum depth of immersion in mercury will be the minimum required to yield an. accurate bulk volume. The plug must be weighed within +0.001 g before and after the mercury immersion to check for mercury intrusion. Any weight gain greater than 0.04 g (0.0030 cc out of 42 cc approximate bulk volume) will be significant intrusion. Bulk volume will be increased to correct for the calculated mercury intrusion. Correction for Grain Loss Grain loss is being measured and corrections for this will be made. The ratio of weight to pore volume is assumed to be constant for the grains lost. The correction will be made using the following equation: Ws + Wg! Vp Vpc - Ws Wg] = Wd - Wthi - Wbi - Ws 14 August 3, 1992 where Vp Vpc Wbi Wgl Ws Wthi Pore Volume in cubic centimeters Pore Volume corrected for grain loss in cubic centimeters Initial weight of bag in grams Dryweight of sample, bag and thimble in grams Weight of grain loss during analysis in grams Weight of sample used in pore volume calculation in grams Initial weight of thimble in grams This correCted pore volume will be used to calculate both oil and water saturations. Permeability to Air Permeability to air is measured on all routine horizontal core plugs (not measured for endpieces). The fine materials generated while sawing should be cleaned from the plug faces before this measurement is made. Use 2% sodium Chloride brine and a sonic cleaner. Clean each end of the core plug and then dry the plug overnight in a vacuum oven at 180 °F. Samples will be weighed to stability following the same procedures specified after cleaning. Then proceed with measurement of permeability. Permeability is measured with 400 Psi net overburden pressure. Complete recalibration of permeameter will be performed every two wells. Check plugs of known permeability will be used to check calibration daily. Permeability should be measured with a stable air flow rate. Routine horizontal core plugs will be used in this measurement only after the completion of bulk volume. Tracer Analysis All on-site routine core plugs and off-site routine core plugs will be analyzed for tracer. Routine core plug endpieces will be analyzed for tracer once every 6 feet for both on-site and off-site samples. The tracer analysis will be conducted on routine core plugs and endpieces to provide an indication of filtrate invasion. The drilling mud filtrates generated, above will also be analyzed to determine filtrate saturation. Iodonaphthalene will be the tracer. An alternate tracer (LVT-200) would be used in the event of a problem with analysis for iodonaphthalene. Gas chromatography with an electron capture detector (ECD) will be used to detect the iodonaPhthalene. The flame ionization detector (FID) will be used to detect LVT-200 and plugging oil. A splitter before the detector will be used in the analysis so that the ECD and FID analyses are generated simultaneously. An injection port splitter is being used to separate the toluene so that rotary eVaporation is not required to analyze for plugging oil and LVT-200. The plugging oil analysis will be quantitatiVe. The LVT-200 analysis will be only qualitative but can be made quantitative if needed. The LVT-200 will be readily apparent on the chromatogram any time its concentration in the oil exceeds about 5%. The procedures for quantitative analysis of iodonaphthalene and plugging oil are in Appendix I. Chromatographic analyses will be performed by an outside lab. Tightly capped and taped containers of the toluene will be transfered to that location from ARCO's Plano lab cold storage. The address for shipping and analysis is in the appendix. The outside lab will conduct analyses for tracer in the toluene mixture and in the drilling mud filtrates. The outside lab will provide for each sample a sample description, weight of sample upon receipt, tracer concentration (ppm) from analysis, dilution factor, total tracer concentration (ppm), and weight percent plugging fluid. The data will be provided by the outside lab to Core Laboratories in the form of an IBM PC floppy disk. The appendix contains a calculation procedure for filtrate saturation, plugging fluid saturation and corrected oil saturation in the routine core and endpieces at the surface. 15 August 3, 1992 Core Slabbing Core slabbing may be conducted when the schedule permits and when the Operating Company representative decides. The core will be depreserved 10 feet at a time. The core pieces will be fit together so that the same side of the core is always presented in the slab. The core will be slabbed 1/4- 3/4 so that the bedding and dip angle are clearly observable. The 3/4 slab should retain the white and yellow stripe and depth markings made at the well site. Rotate the core 90° clockwise looking up hole from these markings and cut the slab. The white and yellow markings are on the updip side of the core. Plugs cut from 3/4 section on the slab side will be parallel to bedding. Slabbing should be conducted using cooled nitrogen to cool the saw blade. Double stripe the 1-inch slab for orientation. The 3/4 butt end of the core will be immediately represerved in order to minimize exposure. The preservation procedure used will be identical to the initial preservation in the field: six layers of Saran wrap, three layers of aluminium foil, and two dips of Core Seal. The routine core analysis sample was slabbed at the time of plugging. This slab should be placed in a slab box in styrofoam inserts to prevent breakage and in depth sequence with the rest of the slab. The routine core analysis 3/4 section should remain preserved. This section could be used to obtain a vertical core plug adjacent to the horizontal plug for permeability measurement. Preservation of the core will make it easier to extract the crude oil since the sample will not be dried out. The slab will be placed in slab boxes with styrofoam inserts after slabbing. Future Uses of the Preserved Core The 3/4 butt end of the core which has been preserved will provide a future source of core for formation damage, vertical permeability, chloride measurements, relative permeability, etc. It is not known at this time how much of these data can be justified for reservoir engineering .purposes, so data acquisition will be delayed until the needs are better defined. A 3/4 slab is called for above since it will allow a 2- to 2.5-inch long plug to be obtained parallel to bedding. A 2/3 slab will only allow a 1.5- to 2-inch long plug which may not be adequate for some lab tests. 16 Sample Identification August 3, 1992 SCF SCL SCFEP SCLEP Field routine horizontal core plug, 1 1/2"x I 1/2" Laboratory routine horizontal plug 1 1/2" x 1 1/2" End piece of field routine horizontal plug, I 1/2" x 1" End piece of laboratory routine horizontal plug, 1 l/2":x 1" 17 Table 2 Sampling and Analysis Frequency *** August 3, 1992 Sample SCF SCL SCFEP SCLEP Sample Location Field Lab Field Lab Sample Data Data Freq Type Freq Tumm~und 1/FF o,S,T 1/FT 2 Weeks 1/3FT* o,S,T 1/31ZT 2 Weeks 1/FT o,S,T 1/6FT 2 Weeks :I/3FT* o,S,T 1/6FT** 2 Weeks In later wells field samples may not be taken and lab sample frequency will increase to one per foot. May be increased or decreased in later wells since samples will be stored. This sampling and analysis frequency will hold for at least two wells after which the data will be reviewed for establishing amount of field versus laboratory sampling in future wells. 18 A t~gust 3, ] 992 Appendixes 19 August 3, 1992 Tracer Analysis In Drilling Fluids, Core Extracts (Revised Method) Scope: The purpose of this procedure is to provide accurate quantification of drilling mud and cutting fluid in Point Mclntyre core. To accomplish this, a halogenated tracer (1-iodonaphthalene) is added to the drilling fluid at a concentration of =30 ppm anc~ a "pure" component (hexadecane) is used as a cutting fluid. Each core sample is extracted with approximately 125 mi of reagent grade toluene. The subsequent core extracts are analyzed by gas chromatography (GC) utilizing an electron capture detector (ECD) and a Flame Ionization Dector (FID). The degree of core invasion by the drilling mud is based on the concentration of tracer contained in the toluene extract and the pore Volume of the extracted core plug. In a similar fashion, the cutting fluid (hexadecane) invasion is based on the concentration of the hexadecane in the toluene extract. . . Instrumentation--Hardware (1) HP-5880A Gas Chromatograph--Level 4 (2) HP Model 7364 Autosampler (3) HP Model 19312 Nickel 63 Electron Capture Detector (4) · (5) Valco Three Port Valve High Temp (6) ' Valc° 1/16" 304 ss Tee (7) HP Auto Sampler Vials and Caps PE/Nelson 25 m X .53 mm ID~0.5 m Film #N931-2689 (8) I ml Glass Disposable Pipettes or Equivalent Eppendorf Pipettes Reagent5 (1) (2) (3) ' (4) (5) (6) l-lodonaphthalene; Eastman Part #2256 Reagent Grade Toluene 1-1ododecane; Aldrich Part #23,825 -2 2 ppm lododecane and 1.0 % Squalane in TolUene Standards of l-lodonaphthalene (0'~02 ppm to 2.0 ppm) in Toluene and Crude Oil (20:1 Point Mclntyre Crude Oil 5qualane; Aldrich Part #23,431 - 1 20 GC---Conditiol'~s Oven Profile Initial Temp Initial Time Program Rate Final Temp Detector and Injector Detector Temp ~ Injector Temp Detector Attenuation Injection Volume; Gas Flows Column Flow Nitrogen Makeup Splitter Flow Septum Purge 75°C 2.00 min. 20°/min. 300° C = 325° C = 300° C = 28 = 5.0 gl = 9.5 cc/min. = 100 cc/min. = 50 cc/min. = 3.5 cc/min. August 3, 1992 Analytical Procedlllre (.1) .- Upon receipt, each sample bottteis. Wei:ghed. to the nearest tenth of a gram and recorded-in-a sample: log book. The samples will be refrigerated at ali times when not being processed. · ~' ~::~;: .! . ~ - . ...... (2a) .A 0.5 mi aliquot of each samPle is diluted 1:1 by volume with the internal standard solution (i.e., 2 ppm Iododecane and 1.0 % Squalane in. Toluene). (2b) In the case of the concentrated drilling fluid solutions it will be necessary to predilute them ~0.4 g of sample to 10.00 gm with reagent toluene. Actual weights are recorded to the nearest milligram along with the respective dilution factor. (3) 5.0 gl of the sample/internal standard blend is injected into the GC splitter via the auto sampler and data acquisition is initialized. (4) After the internal standard'and tracer have eluted the three-port valve is actuated and the oven temperature allowed to proceed to its maximum setting. (5) From the. ECD, the concentration-of the tracer is determined using the 1 ppm iododecane peak'as an internal standard along with the response factor relating area counts to concentration. The internal standard is used to correct fOr variatiOns in sample size reaching the detector. (6) FroTM the FID, the concentration of the Cutting fluid is determined using the 0.5% Squalane peak as an internal standard along with :the response factor relating area counts 'to concentration. (7) The measured tracer concentration is to be adjusted for any dilutions and then reported as ppm tracer. (8) The measured cutting fluid's concentration is to be adjusted for any dilutions and then reported as 21 (9) .~ .... ',7~ ~ '.~ August 3, 1992 percent cutting fluid. A three-point calibration curve of tracer in toluene and crude oil will be run daily. Response factors will be calculated from the calibration curve and a running log of the calculated response factor versus time will be maintained daily. Shipping Address for Toluene/Mud Filtrate Samples Mr. WaYne Kriel ARCO Exploration and Production Technology 2300 Plano Parkway piano, Texas 75075 (214) 754-6069 Toluene samples will be placed in cold storage in ARCO's core storage facility and transfered for analysis in lots of 50 to.60 samples' to: Mr. Wayne Britton 1548 Valwood Parkway, Suite 106 Carrolton, Texas 75006 (214) 241-8374 CALCULATION OF FILTRATE SATURATION AND PLUGGING FLUID SATURATION DEFINITION OF TERMS floppy disk from CPM Lab (ppm) Crt - n n at'ion ftra rin her luenefr m h D an tark This value will u li dail n to i kfr m PM m Cht - · :. . . value w~il be su hed dml on a to disk from CPM Lab wei ht ercent Ff - weight fraction of filtrate in the oil in the core So - saturation of oil phase in core, including reservoir oil, mud filtrate and plugging fluid (%pv) So corr , saturation of oil.'in core corrected for mud filtrate and plugging fluid invasion(%pv) Sol - saturation of filtrate in core (%pv) Sob - saturation of plugging fluid, hexadecane, in core (%pv) Vp - .pore volume of the core (cci Wcd - weight of dry COre (g) Wci - _weight of core before Dean Stark Wco - _weight of core after Dean Stark Wfl _ ~weight of dry Dean Stark flask (~ Wloss - weight of toluene lost as vapor (g) Wo - weight of oil phase in the core (g) Woe - weight of crude oil extracted from core into toluene (g) Wof - weight of filtrate extracted from core (g) Wop - weight of plugging oil extracted from core (g) Wot - weight of residual oil left in core after Dean Stark (g) Wtl - w iht f flaskand lu n f an ark Wt2 - wel htf lu n d il fil at lu 'n il andfla k after Dean Stark Wtc - weight of toluene left in core after Dean Stark (g) Wti - weight of toluene charged to flask before Dean Stark (g) Wto - weight of toluene and other oils remaining in the flask after Dean Stark (g) Ww - ~we~ght of water d/stilled from core (e) The underlined terms are measured in the analysis. The other terms may be calculated, but not all these calculated terms will be needed for the final report. Those which are needed will be identified below. EOIdATION ! gives the weight of toluene charged to the flask W~ = Wtl - Wn (1) E_OUATION 2~ gives the weight of toluene plus other oils in the flask after Dean Stark extraction is complete. (includes the toluene in side arm) Wto = Wa - Wtl (2) August 3,1992 EOUATIQN ~t gives the weight of toluene as the sum of all fluids in the flask after Dean Stark extraction. Wto = Wti + Woe + WoP + Wof- Wloss - Wtc (3) EOUATION 4 gives the total weight of oil phase in the core before Dean Stark extraction. Wo = Wci - Wcd - Ww (4) EOUATION 5 gives the total weight °fthe components in the oil phase in the core. - . . Wo = Woe + Wot + Wop + Wof (5) EOUATION 6 gives the toluene Vapor lost from the Dean Stark extractor in terms of the other weights which are measured. This equation is the result of combining equations I through 5. Wloss = Wtl - Wt2 + Wci - Wco - Ww (6) EOUATION 7 gives thecalCUlati0n 0i~ f-iltrate weight fraction in the oil in-the core. Ff = Ctt/Cm*{Wto/Wo} (7) -. EOUATION 8 gives the saturation of filtrate in the core. This value will be printed out with the routine core data. . Sof = 100*(Wo*Ff/0.85)/Vp (8) The value, 0.85 g/cc, is an average value for the density of the oil which is a combination of plugging oil, 0.77 g/cc, filtrate, 0.82 g/cc, and crude oil, 0.875 g/cc. the composition assumed is 20 % plugging oil, -10 % filtrate and 70 % stock tank oil by weight. This value can be refined, if needed, since the oil Phase will be chromatographically analyZ~l.. There are no significant assumptions in the calculations except that recovery of the tracer is quantitative and no losses when cutting plugs. Tests conducted with Point Mclntyre core used for damage tes. ting indicate tracer.recovery from the core is quantitative. 99.6% of the tracer was recovered by the Dean Stark procedure. Please note: The tracer could show up in the side arm and could also be found in the toluene in the core. The retained toluene volume in the core is usually a small fraction of the total toluene so that is not a significant error. 24 August 3,1992 EOUATION 9 gives the saturation of plugging fluid in the core. This value will be printed out with the routine core .data. Soh : (Wto*Cht/0.77)/Vp (9) The value, 0.777 g/cc, is standard Value for the density of plugging oil, hexadecane. Contamination of cores by plugging fluid was 18.1% and 18.7% of the oil phase weight in two tests. These lab tests indicate there is some replacement of in-place oil by plugging fluid, but 75% of the oil originally present remained in the core after plugging. This is very consistent with Exxon's findings for Prudhoe. EOUATION-10 gives the oil saturation corrected for mud filtrate and plugging fluid in the core. This' value will be printed out with the routine core data. So corr = So - Sol - Sob ' ' (10) Core Labs should provide a spread sheet of all weights measured in the core analysis. August 3,1992 Flow Charts · ._ .26 CO~E ANCHORAGE PROCEDURES (WITH WELL SITE PLUGGING) LAYOUT DEPTH ORDER, GAMMA LOG SEPARATE/DEPRESERVE SCF SECTIONS DRY SAW 2" WHOLE CORE 1" SLAB, DOUBLE STRIPE DRILL SCL PLUGS DRY TRIM sCL?ENDpIEcE (SCLEP) PRESERVE SCL/SCI FP IN SARAN & FOIL f WEIGH SCI../SCLEP, SARAN & FOIL SEAL&TAPE IN GLASS CONTAINERS .- (MAINTAIN @ 50°F UNTIL USE) -- REPRESERVE 3/4 WHOLE SCF PLUGS/SCFEPS PREBOII~TOLUENE WEIGH FLASK WEIGH PRESERVED PLUG/EP DEPRESERVE SCI../SCF PLUG OR EP sCL/SCF PLUG OR EP WEIGHT : · DEAN-STARK SCL/SCF PLUGS & SCLEPS (MIN.12 HRS) WATER ~OLUME PLACE PLUG OR~EP & BAG INVVEIGHED AND PREDRIED THIMBLE CHLOROFORM/METHANOL, 87/13 CORE REMNANT CLEAN SCI_/SCF PLUG OR EP (2-4 DAYS) '(elapsed-time)- -. coNV~C~-0-N: - DRY FOR 4 HRS :.. ,VACUUMOVF. N._DRY@ 180°F PLUG OR DEPRESERVE CORE EP TOCONSTANT WEIGHT TAKE STATE CHIPS (IF NOT TAKEN ON THE SLOPE) SLAB - , I 1/4 3/4 f -" DOUBLE STRIPE R~PR~SI~NE TOLUENE WEIGHT IN FLASK -- PHOTO CORE SEAL BOX BOX WEIGHPLUG/EP, BAG & TIMBLE REMOVE PLUC.~~IGH PLUC.~P HEUUM GRAIN VOLUME · . 1~ SCL/SCF PLUG OR EP WEIGHT MERCURY POROSIMETER BULK VOLUME SOb~F ~_UG OR E~ WEIOHT 2%' BRINE SONIC. CLEANING OF PLUG ? vAcuUM OVEN DRY @ 180°F SCI. JSCF pLUG OR EP TO :CONSTANT WEIGHT PERMEABILITY TO AIR (EXCEPT FOR EP) REPRESERVE PLU.~P IN SARAN/FOIL REPLACE/SEAL IN BO'I-rLE FOR STORAGE MUD SAMPLES / 8/3/92 FILTER PRESS @ 500 PSI & 150°F (1 HR OR 2cc COLLECTED) SEAL/TAPE GLASS CONTAINER LABEL W/CORE NO., CORE DEPTH, WELL NAME & DATE PLANe (1 DAY SHIPPING) SEAL/TAPE GLASS ~AINER LABEL W/CORE NO., CORE DEPTH, VVELL - NAME & DATE PLANe (1 DAY SHIPPING) CO~E ANCHORAGE PROCEDURES (NO WELL SITE PLUGGING) LAYOUT DEPTH ORDER, GAMMA LOG SEPARATE/DEPRESERVE SCL SECTIONS 1" SLAB, DOUBLE STRIPE DRILL SCL PLUGS DRY TRIM SCL ENDPIECE (SCLEP) PRESERVE SCL PLUG & SCLEP, SEAL/TAPE IN GLASS CONTAINER (MAINTAIN @ 50°F UNTIL USE) WEIGH SCL/SCLEP PLUG, SARAN & FOIL REPRESERVE 3/4 WHOLE CORE REMNANT [elapsed time) PREBOILTOLUENE WEIGH FLASK ~ WEIGH PRE,~VED PLUG DEPRESERVE PLUG OR EP · , ~ WEIGH PLUG/EP AND PLUG/EP+BAG D J' 'STARK SCUSC[ PLUGS &'SCLEPS (MIN.12 HRS) -WATER VOLUME ! PLACE PLUG/EP & BAG IN PREDRIED & PREWEIGHED THIMBLE ? CHLOROFORM/METHANOL, 87/13 CLEAN SClJSCF PLUG OR EP (2-4 DAYS) 'coNVE~oN OVEN @ 180°F FOR 4 HR ; VACUUM OVEN DRY @ 180°F SAMPLI~S FILTER PRESS @ 500 PSI &150°F (1HR OR 2cc COLLECTED) SEAL/TAPE IN A GLASS CONTAINER LABEL W/CORE: NO., CORE DEPTH, WELL NAME & DATE PLANO (1 DAY TOLUENEINWEIGHT FLASK SHIP~ING) SEAL/TAPE GLASS ~AINER LABEL W/CORE NO;,'- · CORE DEPTH, WELL I PL:,L~ OREP TO CONSTANT WEIGHT NAME & DATE DEF~ CORE WEIGH PLUG/EP, BAG & THIMBLE ~ ' BRUSH'PLUG/EP, WEIGH PLUGAEP PLANO (1 DAY TAKE STATE CHIPS (IF NOT HEUUM G IN VOLUME SHIPPING) TAKEN ON SLOPE) SLAB 1/4 3/4 DOUBLE STRIPE PHOTO CORE SEAL BOX BOX BAYVIEW BAYVIEW 'SCl./SCF PLIL~~ OR EP WEIGHT MERCURY POROSIMETER BULK VOLUME . : .20/0 BRINE SONIC CLEANING OF PLUG ,. -VACUUM OVEN DRY @ 180°F SCL/SCF PLUG OR EP TO,CONSTANT WEIGHT 'PERMEABILITY TO AIR (EXCEPT FOR EP) · REPRESERVE PL~GAEP IN SARAN/FOIL REPLACF. YSEAL IN BOI-i'LE FOR STORAGE WELL SITE OPERATIONS WITH ON-SITE CORE PLUGGING WELL SITE PRESERVATION SET UP PRESERVATION MATERIALS IN TRAILER 1 LABEL (WELL NAME, ~ ANC~RAGE wrI'H CORE CORE NO., DEPTH, DATE) LABEL (WELL NAME, CORE NO., DEPTH, DATE) (1 GALLON) (1 GALLON) LAYDOwN INNER BARREL WIPEDOWN/DEPTH MARK INNER BARREL CUT INNER BARREL (3' LENGTHS) CAP/CLAMP CORE ENDS TRANSPORT TO TRAILER 1 LAYOUT CORE DEPTH MARK CORE SURFACE (STATE CHIP ~ SAMPLES/IORE DESCR~ IF TIME pERMITS) MARK SCF SECTIONS (3' X 4") 1/FT ~ AND SCL SECTIONS (2' X 4') 1/3 FT ' DRY SAW SCF SECTIONS (3' X 4') ........ 1" SLAB SCF SECTION; DOUBLE STRIPE PRESERVE ALL CORE IN SARAN WRAP & FOIL LABEL W/DEPTH, SCF/SCL & DOUBLE sTRIPE TRANSPORT SCF SECTIONS TO TRAILER 2 · CORE SEAL COATING ~ PLACE ALL IN DEPTH SEQUE~ IN CORE BOXES ........ MARK BOXES WITH CORE DEPTH SEAL BOXES WELLSrrE INVENTORY CRATE COFE BOXES ~ ANCHORAGEWITH CORE WELLSITE PLUGGING DRill SCF PLUG DRY TRIM ~ LABEL PLUG OR EP WITH DEPTH / 8/3/92 REPRESERVE SCF REMNAI~/SLAB AS ONE PIECE - · IN SARAN WRAP & AL FOIL LABEL WITH DEPTH MARK, SCF & DOUBLE STRIPE RETURN REPRESERVED SCF RE~/SLAB TO TRAILER 1 ANCHORAGE, 1 CO~IPMENT WEIGH SARAN,~OIL + SAMPLE (:~-0.01g) KEEP BOTTLES COLD(-50°F) ~ ANCt-iORA~ ? LABEL FOIL VV1TH ~_UG OR EP DEPTH SEAI. JTAPE SEPARATELY IN GLASS BOTi'LES WELL SITE OPERATIONS WITHOUT ON-SITE CORE PLUGGING WELL SITE PRESERVATION SET UP PRESERVATION MATER.S IN TRN! FR 1 MUD SAMP~ ~ LABEL (WELL NAME, (1 GALLON) CORt4G (1 GALLON) LAYDOWN INNER BARREL WIPEDOWN~EPTH MARK INNER BARREL CUT INNER BARREL (3' LENGTHS) CORE NO., DEPTH, DATE) LABEL (WELL NAME, CORE NO., DEPTH, DATE) CAP/C~MP CORE ENDS TRANSPORT TO TRAI~R 1 LAYOLrr CORE '- ~ DEPTH MARK CORE SURFACE (STATE CHIP MARK SCL SECTIONS (3" X 4") I~T DRY SAW SCL SECTIONS (3' X 4') PRESERVE CORE IN SARAN WRAP & FOl ~BEL DEPTH, SCL & DOUBLE STRIPE CORE SEAL COATING PLACE ALL IN DEPTH SEQUENCE IN CORE BoXEs SEA~ BOXES WEU~ffE ~VENTORY ANCHORAGE WITH CORE ANCHORAGE WITH CORE / 8/3/92 SECTION 5 DATA DISKETTE B~/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: P1-20 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/07/92 11:00 SPUD: 10/08/92 09:00 RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 10/08/92 (1) TD: 110'( 0) 10/09/92 (2) TD: 1143' (1033) 10/10/92 (3) TD: 3500' (2357) 10/11/92 ( 4) TD: 3500' ( 0) 10/12/92 ( 5) TD: 4300' ( 800) 10/13/92 (6) TD: 6000' (1700) 10/14/92 ( 7) TD: 6650'( 650) 10/15/92 (8) TD: 7883'(1233) RIG UP. MW: 8.5 VIS: 0 MOVE RIG F/ Pi-ll TO P1-20. RIG ACCEPTED @ 23:00 HRS, 10/7/92. N/U DIVERTER. DRLG. MW: 8.8 VIS:120 TEST DIVERTER. M/U BHA #1. SPUD WELL @ 09:00 HRS, 10/8/92. DRLG F/ 48'-244' POOH. CHANGE BHA. DRLG F/ 244'-512'. CIRC. SURVEY. DRLG F/ 512'-960'. CIRC. SURVEY. DRLG F/ 960'-1143' CIRC. MW: 9.4 VIS: 78 DRLG F/ 1143'-1239'. SHORT TRIP. REAM TO 1239' DRLG F/ .1239'-1514'. CIRC. DRLG F/ 1514'-1972' CIRC. DRLG F/ 1972'-2433'. CIRC. SHORT TRIP TO 1146' DRLG F/ 2433'-2526'. CIRC. DRLG F/ 2526'-2985' CIRC. DRLG F/ 2985'-3500' CBU. N/U BOPE. MW: 9.4 VIS: 42 CIRC. 13 STDS SHORT TRIP. CIRC. POOH. L/D BHA. RIH W/ 13-3/8" CSG. CIRC. PUMP 100 BBLS WATER, 1500 SX (580 BBLS) 'E' PERM CMT @ 12.2 PPG, 400 SX (80 BBLS) 'G' CMT @ 15.8 PPG. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. N/D DIVERTER. TOP JOB W/ 250 SX CSII @ 15 PPG. N/U BOPE. DRLG. MW: 9.1 VIS: 40 N/U BOPE. TEST BOPE. RIH W/ BHA #2. CIRC. TEST CSG. DRLG FC, CMT. TEST CSG. DRLG CMT, FS, TO 3510' CBU. LOT (12 PPG EMW). DRLG F/ 3510'-4300' DRLG. DRLG F/ 4300'-5350' DRLG F/ 5350'-6000'. MW: 9.4 VIS: 38 SHORT TRIP. REAM THRU TIGHT SPOTS. DRLG. MW: 9.5 VIS: 39 DRLG F/ 6000'-6470' CBU. POOH. CHANGE BIT. RIH. DRLG F/ 6470'-6602' POOH. CHANGE MTR. RIH. DRLG F/ 6602'-6650' DRLG. DRLG F/ 6650'-7883' MW: 9.7 VIS: 38 A~aska {;il & Gag 8ons. Anchorage WELL : P1-20 OPERATION: RIG : POOL 7 PAGE: 2 10/16/92 (9) TD: 8690'( 807) 10/17/92 (10) TD: 8895' ( 205) 10/18/92 (11) TD: 9200'( 305) 10/19/92 (12) TD: 9637' ( 437) 10/20/92 (13) TD: 9637' ( 0) 10/21/92 (14) TD: 9637' ( 0) 10/22/92 (15) TD: 9656' ( 19) 10/23/92 (16) TD: 9764' ( 108) 10/24/92 (17) TD: 9865' ( 101) 10/25/92 (18) TD: 9941' ( 76) DRLG. DRLG F/ 7883'-7980' 7980'-8690'. MW: 9.8 VIS: 37 CBU. SHORT TRIP 15 STDS. DRLG F/ RIH W/ LOGS. MW:10.0 VIS: 41 DRLG F/ 8690'-8895' CIRC. POOH. P/U ANADRIL CDR TOOL. RIH TO 7138'. LOG TO BTM. RIH W/ LOGS. MW:10.1 VIS: 46 RIH W/ LOGS. DRLG F/ 8895'-9200'. CBU. POOH. CHANGE BHA. RIH TO 9120'. LOG TO BTM. POOH. MW:10.2 VIS: 41 RIH W/ LOGS. DRLG F/ 9200'-9520'. RELOG F/ 9490'-9520' DRLG F/ 9520'-9637' CBU. SHORT TRIP TO 9176' CBU. POOH. CLEANING ANNULUS. MW:10.1 VIS: 38 POOH. TEST BOPE. R/U WOTCO. RIH W/ 9-5/8" CSG. CIRC @ SHOE. RIH W/ CSG. R/U CMT HD. CIRC. PUMP 20 BBLS ARCO PREFLUSH, 50 BBLS ARCO SPACER, 140 SX 'G' CMT W/ .5% CFR-3, 3% ECONOLITE, .4% HALAD 344 @ 11.1 PPG & 600 SX 'G' CMT W/ .2% CFR-3, .2% HALAD 344, .25% HR-5 @ 15.8 PPG. BUMP PLUG W/ 2000 PSI. N/D BOPE. SET SLIPS. CIRC. MW:10.1 VIS: 90 INSTALL SPOOL. N/U BOPE. TEST BOPE. L/D BHA. M/U BHA. RIH. CIRC @ 9555'. TEST CSG. DRLG FC, CMT, FS, 1' NEW HOLE. CBU. LOT (12.5 PPG EMW). CIRC. CORING. MW:10.2 VIS: 90 CIRC. DISP WELL W/ 10.2 PPG CORE FLUID. POOH. L/D BHA. RIH W/ CB %1. CBU. CORE F/ 9646'-9656' POOH. MW:10.3 VIS: 88 CORE F/ 9656'-9705' CBU. POOH. L/D CORE %1. RIH W/ CB #2. CBU. CORE F/ 6705'-9764' CBU. POOH. CORING. MW:10.2 VIS: 85 POOH. L/D CORE #2. RIH W/ CB. CBU. CORE F/ 9764'-9823' CBU. POOH. L/D CORE #3. RIH W/ CB. CBU. CORE F/ 9823'-9865' RIH. MW:10.2 VIS: 78 CORE F/ 9865'-9882' CBU. POOH. L/D CORE #4. RIH W/ CB. CBU. CORE F/ 9882'-9941' CBU. POOH. L/D CORE #5. RIH w/ CB. A~s.ka Off & Gas Cons. Commission A~chora~e WELL : P1-20 OPERATION: RIG : POOL 7 PAGE: 3 10/26/92 (19) TD:10089' ( 148) 10/27/92 (20) TD:10237' ( 148) 10/28/92 (21) TD:!0270'( 33) 10/29/92 (22) TD:10500' ( 230) 10/30/92 (23) TD:10500' ( 0) 10/31/92 ( 24) TD:10500 PB: 0 11/01/92 (25) TD:10500 PB:10408 11/02/92 (26) TD:10500 PB:10408 POOH. MW:10.2 VIS: 82 RIH. CBU. RIH_ CORE F/ 9941'-10000'. CBU. POOH. L/D CORE #6. RIH W/ CB. CBU. CORE F/ 10000'-10089'. CBU. POOH. L/D CB. MW:10.2 VIS: 85 L/D CORE #7. RIH W/ CB. CBU. CORE F/ 10089'-10178' CBU. POOH. L/D CORE #8. RIH W/ CB. CBU. CORE F/ 10178'-10237'. CBU. L/D CORE #8. L/D CORE EQUIP. DRLG. MW:10.2 VIS: 76 L/D CB. TEST BOPE. RIH W/ DRLG BHA. MAD RUN F/ 9637'-10237' DRLG F/ 10237'-10270' R/U ATLAS. MW:10.2 VIS: 66 DRLG F/ 10270'-10500' TD WELL @ 20:30 HRS, 10/28/92. CBU. SHORT TRIP TO 9~30' CBU. POOH. R/U ATLAS. RIH W/ 7" LNR. MW:i0.3 VIS: 90 LOG RUN: GR/CN/ZDL/DIFL. LOG RUN: MAC/GR. R/D ATLAS. RIH W/ BHA. CBU. POOH. L/D BHA. RIH W/ 7" LNR. RIH. MW:10.4 OBM RIH W/ 7" LNR ON DP. CIRC @ SHOE. RIH. CIRC. CMT LNR. DISP W/ MUD. SET HGR & PKR W/ 4000 PSI. RELEASE F/ HGR. REV CIRC. POOH. RIH W/ CSG SCRAPERS. N/U TREE. MW: 9.8 NaCl RIH. TAG LC @ 10408'. CBU. TEST CSG, LNR TOP PKR. CIRC. DISP WELL W/ 9.8 PPG NACL. POOH. DISP TOP 600' W/ DIESEL. POOH. L/D BHA. N/U TREE. RIG RELEASED. MW: 9.8 NaCl N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 10:00 HRS, 11/1/92. SIGNATURE: (drilling superintendent) DATE: AJask.~,' 2 Oil & Gas Cons. Cornmissioi", Anchorage ,Bp/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: P1-20 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 01/02/93 05:00 SPUD: RELEASE: 01/05/93 10:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 16 01/03/93 (1) TD:10500 PB:10408 01/04/93 (2) TD:10500 PB:10408 01/05/93 (3) TD:10500 PB:10408 R/U ATLAS. MW: 9.8 NaC1 MOVE RIG. RIG ACCEPTED @ 17:00 HRS, 1/2/93. N/D TREE. N/U BOPE. PULL HGR. TEST BOPE. REV OUT DIESEL. N/U LUB. R/U ATLAS. RIH W/ PERF GUNS. L/D DP. MW: 9.8 NaCl PERF W/ 4" PERF GUN, 4 SPF F/ 9264'-9310' RUN GR/JB TO 9650' R/D ATLAS. N/D LUB. RIH W/ 9-5/~" & 7" PKRS. R/U ATLAS. RIH W/ GR. SPACE OUT. POOH. SET PKRS W/ 2500 PSI & 3500 PSI. TEST PKRS. OK. POOH. L/D DP. RIH W/ 4-1/2" TBG. MW: 9.8 NaCl L/D DP. R/U TBG RUN EQUIP. STRAP TBG. RIH W/ 4-1/2" 13 CR TBG. 01/06/93 (4) TD:10500 PB:10408 RIG RELEASED. MW: 9.8 NaCl RIH W/ 4-1/2" 13 CR TBG, SSSV, CNTL LINES. STING INTO PKR. SPACE OUT TBG. M/U TBG HGR. HOOK UP CNTL LINES. TEST SAME. DISP 235 BBLS DIESEL DN TBG. LAND TBG. TEST TBG, ANNULUS. OK. SET BPV. L/D LAND JT. N/D BOPE. N/U TREE. TEST TREE. TEST TBG, ANNULUS. OK. SECURE WELL. RIG RELEASED @ 22:00 HRS, 1/5/93. MOVE RIG TO M-19A. SIGNATURE: (drilling superintendent) DATE: ataska Oil a Gas Cons. Commissiol~ Anchomg~ SUB - SURFA CE DIRECTIONAL SURVEY r-~ UIDANCE ~'J ONTINUOUS J'~ OOL Company Well Name Field/Location ARCO ALASKA, INC. P1-20 (1384' FSL, 908' FEL, SEC 16, T12N, R14E) POINT NCINTYRE, NORTH SLOPE, ALASKA Job Reference No. · 92660 Logc~ed By: SCH'dARTZ Date 02-NOV-92 Computed By: KRIJ~LL . SCHLUI~IBEROER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC, P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA SURVEY DATE' 2-NOV-92 ENGINEER- SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION' LINEAR VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 9 DEG 3I MIN WEST ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE' 8-NOV-92 TRUE SUB-SEA COURSE MEASLRED VEETICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 699 99 799 99 899 99 PAGE 1 DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 1000 O0 -50 80 49 20 149 20 249 20 349 20 449 20 549 20 649 19 749 19 849 19 999.99 949 19 19 19 19 19 18 18 18 18 17 0 0 N 0 0 E 0 5 S 68 35 E 0 4 S 5 7 E 0 7 S 11 36W 0 18 S 18 23 E 0 20 S 18 52 E 0 17 S 0 42 W 0 19 S 1 52W 0 18 S 3 58W 0 17 S 4 43W 1100 1200 1300 1400 1500 1600 1700 1800 1900 0 14 S 1 42 W 0 13 S 5 0 W 0 19 S 22 4 E 0 19 S 48 21E 0 18 S 56 23 E 0 19 S 64 17 E 0 18 S 69 42 E 0 36 S 73 50 E 0 35 S 82 59 E 0 47 N 83 25 E O0 1099.99 1049 O0 1199.99 1149 O0 1299'.99 1249 O0 1399 99 1349 O0 1499 98 1449 O0 1599 98 1549 O0 1699 98 1649 O0 1799 98 1749 O0 1899 97 1849 FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -0 01 -0 13 -0 30 -0 59 -1 21 -1 76 -2 28 -2 81 -3 30 -3 75 -4 07 -4 50 -5 04 -5 39 -5 75 -6 01 -6 42 -6 78 -6 96 O. O0 0.11 0.11 O. O0 O. 09 O. 25 O. O0 0. O0 0.11 O. O0 0 O0 0 0 0 0 0 0 0 0 0 22 10 O0 O0 29 O7 02 O0 19 0 O0 N 001S 0 11 S 0 29 S 0 58S 1 17 S 171S 2 24 S 2785 329 S 3755 4 07 S 4 505 4 99 S 5 27 S 5 565 5 74 S 6 03 S 6 23 S 6 215 O00E 004 E 0 15E 0 10 E 0 13 E 036 E 042 E 041E 038 E 034 E 031E 0 29 E 0 37 E 0 70 E 1 13 E 1 62 E 208 E 2 85 E 3 84 E 5 03 E 000 N 0 OE 04 S 83 8 E 18 S 54 26 E 30 S 19 16 E 59 S 13 0 E 22 S 17 14 E 76 S 13 46 E 28 S 10 22 E 81 S 7 47 E 31 S 5 59 E 3 76 S 4 47 E 08 S 4 3 E 52 S 4 40 E 04 S 7 57 E 39 S 12 8 E 79 S 16 14 E 11 S 19 57 E 67 S 25 19 E 32 S 31 37 E O0 S 39 0 E 2000 O0 1999.96 1949 16 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2099.95 2049 O0 2199.94 2149 O0 2299.94 2249 O0 2399.93 2349 O0 2499.92 2449 O0 2599.90 2549 O0 2699.85 2649 O0 2799.79 2748 O0 2899.75 2848 15 14 14 13 12 10 05 99 95 3000 O0 2999.72 2948.92 3100 320O 3300 3400 3500 3600 3700 3800 3900 O0 3099.69 3048.89 O0 3199.64 3148.84 O0 3299.58 3248.78 O0 3399.53 3348.73 O0 3499.47 3448.67 O0 3599.39 3548.59 O0 3699.05 3648.25 O0 3798.35 3747.55 O0 3897.52 3846.72 0 50 N 77 42 E 0 41 N 84 5 E 0 39 S 83 2 E 0 37 S 80 27 E 0 45 S 89 19 E 0 57 N 81 8 E I 35 N 59 14 E I 57 N 37 47 E I 47 N 35 22 E I 33 N 42 I E 1 26 N 46 53 E I 35 N 43 8 E I 54 N 27 23 E I 53 N 19 4 E I 53 N 16 35 E I 54 N 15 52 E 3 13 N 8 24 E 6 7 N I 48 W 7 6 N 4 5 W 7 49 N 5 57 W -6 94 -6 94 -7 11 -7 48 -7 77 -7 92 -7 56 -5 78 -3.40 -1.51 0.01 I 43 3 68 6 49 9 43 12 40 16 02 23 98 35 69 48 50 0 O0 0 O0 0 O6 0 07 0 O8 0 23 I 22 0 48 0 56 0 O3 0 01 0 91 0 59 0 24 0 O0 0 O0 3 14 2 46 0 61 1 94 5 96 S 5 73 S 5 73 S 5 91 S 6 O1 S 5 91S 5235 3 03 S 0 30 S 1 91N 3 76 N 5 50 N 8 09 N 11 15 N 14 29 N 17 47 N 21 28 N 29 41 N 41 17 N 53 98 N 646 E 7 75 E 8 86 E 9 97 E 11 12 E 12 61 E 14 52 E 16 85 E 18 75 E 20 52 E 22 35 E 24 16 E 25 98 E 27 24 E 28 23 E 29 15 E 30 04 E 30 36 E 29 67 E 28 63 E 8 79 S 47 19 E 9 10 11 12 13 15 17 18 20 64 S 53 29 E 55 S 57 8 E 59 S 59 19 E 64 S 61 37 E 92 S 64 52 E 44 S 70 11E 12 S 79 48 E 75 S 89 4 E 61 N 84 40 E 22 66 N 80 28 E 24 27 29 31 33 36 42 5O 61 78 N 77 10 E 21 N 72 42 E 44 N 67 45 E 64 N 63 9 E 98 N 59 4 E 82 N 54 41E 27 N 45 55 E 75 N 35 47 E 10 N 27 56 E ARCO ALASKA INC. Pi -20 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE' 8-NOV-92 PAGE 2 DATE OF SURVEY' 2-NOV-g2 KELLY BUSHING ELEVATION' 50.80 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3996,36 3945 56 9 46 N 11 17 W 4100.00 4094.58 4043 4200.00 4191 79 4140 4300 O0 4287 63 4236 4400 O0 4381 86 4331 4500 O0 4474 97 4424 4600 O0 4566 10 4515 4700 O0 4654 96 4604 4800 O0 4743 35 4692 4900 O0 4829 99 4779 78 12 2 N 10 35 W 82 99 15 1 N 13 15 W 105 83 18 11 N 17 27 W 134 06 20 37 N 17 11W 167 17 22 28 N 16 59 W 203 30 26 15 N 16 27 W 244 16 27 42 N 16 24 W 289 55 28 25 N 16 22 W 336 19 31 28 N 16 5 W 385 63 68 41 79 09 24 38 19 72 14 72 5000 O0 4914 54 4863 74 32 55 N 16 8 W 438 75 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4998 O0 5082 O0 5163 O0 5243 O0 5323 O0 5404 O0 5484 O0 5565 O0 5646 46 4947 05 5031 57 5112 74 5192 99 5273 31 5353 91 5434 77 5514 62 5595 66 32 54 N 16 7 W 492 25 34 16 N 14 44 W 547 77 36 23 N 13 37 W 605 94 36 47 N 13 26 W 664 19 36 37 N 12 38 W 724 51 36 27 N 11 43 W 783 11 36 6 N 11 32 W 842 97 35 58 N 11 3 W 901 82 36 14 N 11 I W 960 79 34 O8 71 25 76 92 72 55 2.41 3 35 2 73 2 51 I 21 3 11 3 84 0 32 2 12 I 65 0 72 0 37 3 29 I 79 0 39 I 19 0 25 0 20 0 56 I 02 ,68 97 N 26 24 E 73 79 N 20 50 E 87 110 137 169 204 243 287 332 380 431 484 537 593 651 709 767 825 883 941 34 N 22 28 N 17 70 N 10 64 N 0 48 N 10 90 N 22 88 N 35 75 N 48 68 N 62 50 E 90 97 E 111 34 E 138 39 E 169 37 W 204 09 W 244 08 W 29O 25 W 336 18 W 385 19 N 14 27 E 74 N 9 15 E 08 N 4 18 E 64 N 0 8 E 74 N 2 54 W 90 N 5 11W 01 N 6 57 W 23 N 8 15 W 73 N 9 17 W 96 N 76 99 W 438 77 N 10 6 W 24 N 92 07 N 106 27 N 120 39 N 134 48 N 148 74 N 160 72 N 172 41N 184 18 N 195 03 W 492 83 W 547 82 W 605 77 W 665 40 W 724 82 W 784 72 W 843 29 W 902 48 W 961 go N 10 46 W 59 N 11 15 W 45 N 11 31W 19 N 11 41W 83 N 11 49 W 40 N 11 50 W 59 N 11 49 W 43 N 11 47 W 26 N 11 44 W 6000 O0 5726.99 5676 19 36 35 N 11 55 W 1020 02 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5807.36 5756 O0 5887.85 5837 O0 5968 38 5917 O0 6048 98 5998 O0 6129 70 6078 O0 6211 07 6160 O0 6292 72 6241 O0 6374 48 6323 O0 6455 67 6404 56 36 25 N 11 46 W 1079 05 36 26 N 11 24 W 1138 58 36 18 N 11 25 W 1198 18 36 20 N 11 37 W 1257 90 35 50 N 11 22 W 1316 27 35 23 N 11 17 W 1374 92 35 9 N 11 14 W 1431 68 35 14 N 11 39 W 1489 87 36 8 N 12 36 W 1547 47 77 03 19 18 28 98 54 86 0 53 0 0 0 0 0 0 0 0 0 999 50 N 207.33 W 1020 77 N 11 43 W 26 1057 48 1115 57 1173 24 1231 84 1289 07 1346 23 1403 81 1459 88 1516 72 N 219.56 W 1080 86 N 231.46 W 1139 98 N 243 18 W 1198 98 N 255 O0 W 1258 83 N 266 76 W 1317 82 N 278 15 W 1375 45 N 289 38 W 1432 90 N 300 75 W 1490 98 N 312 98 W 1548 27 N 11 44 W 61 N 11 43 W 90 N 11 42 W 10 N 11 42 W 13 N 11 41W 24 N 11 40 W 97 N 11 39 W 56 N 11 38 W 93 N 11 39 W 7000 O0 6536.29 6485.49 36 24 N 13 19 W 1606 91 7100 O0 6616.73 6565.93 36 25 N 13 21W 1666 7200 O0 6697.05 6646.25 36 41 N 13 31 W 1725 7300 O0 6777 21 6726.41 36 44 N 13 45 W 1785 7400 O0 6857 29 6806 49 36 52 N 13 38 W 1844 7500 O0 6937 22 6886 42 36 57 N 13 28 W 1904 7600 O0 7017 14 6966 34 36 58 N 13 13 W 1964 7700.00 7097 10 7046 30 36 49 N 12 46 W 2024 7800.00 7177 14 7126 34 36 50 N 12 4 W 2084 7900.00 7257 18 7206 38 36 51 N 11 25 W 2144 18 62 26 99 92 91 85 71 61 0 36 1574 63 N 326 32 W 1608 08 N 11 42 W O1 1632 18 1690 31 1748 21 1806 21 1865 26 1923 25 1982 61 2040 42 2099 43 n 340 38 N 353 49 N 367 68 N 382 09 N 396 58 N 410 10 N 423 63 N 436 32 N 448 O0 W 1667 81W 1727 90 W 1786 09 W 1846 15 W 1906 04 W 1966 55 W 2026 47 W 2086 64 W 2146 46 N 11 46 W O1 N 11 49 W 77 N 11 53 W 64 N 11 56 W 70 N 12 0 W 80 N 12 2 W 84 N 12 4 W 78 N 12 4 W 72 N 12 4 W ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE: 8-NOV-g2 PAGE 3 DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE MEASURED VERTICAL VERTICAl_ DEVIATION AZIMLF[H SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMl~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IOO FEET FEET FEET DEG ~IN 8000 O0 7337.11 7286.31 37 4 N 10 45 w 2204 68 8100 8200 83O0 8400 8500 8600 8700 8800 8900 O0 7416.86 7366.06 37 9 N 10 6 W 2265 O0 7496.46 7445.66 37 22 N 9 29 W 2325 O0 7575 83 7525.03 37 34 N 9 8 W 2386 O0 7655 O1 7604.21 37 42 N 8 31W 2447 O0 7733 99 7683.19 37 56 N 7 56 W 2508 O0 7812 96 7762.16 37 35 N 8 35 W 2570 O0 7892 26 7841.46 37 38 N 8 25 W 2631 O0 7971 O0 8049 O0 54 37 44 75 09 O1 28 7920.48 38 3 N 7 24 W 2692.27 83 7999.03 38 18 N 6 40 W 2754.09 9000.00 8128 53 8077 73 37 53 N 6 53 W 2815 72 9100.00 8207 9200.00 8288 9300.00 8370 9400.00 8456 9500.00 8544 9600.00 8633 9700.00 8725 9800.00 8816 82 8157 13 8237 87 8320 64 8405 38 8493 86 8583 06 8674 34 8765 9900.00 8907.49 8856 02 37 10 N 7 21W 2876 33 35 44 N 7 34 W 2936 07 32 22 N 6 47 W 2992 84 29 31 N 6 24 W 3043 58 28 5 N 4 5 W 3091 06 24 54 N 0 17 E 3135 26 24 5 N 1 50 E 3175 54 24 11 N 2 18 E 3215 69 24 25 N 2 20 E 3256 59 13 21 53 39 58 85 83 09 10000 O0 8998.40 8947 60 24 50 N 2 27 E 3296 86 10100 O0 9089.13 9038 33 24 49 N 3 7 E 3337 95 10200 O0 9179.81 9129 O1 25 7 N 3 18 E 3379 07 10300 O0 9270.42 9219 62 24 48 N 3 0 E 3420 33 10400 O0 9361.52 9310 72 24 9 N 3 25 E 3460 58 10500 O0 9452.77 9401 97 24 9 N 3 25 E 3500 44 0 38 2158 29 N 460.20 W 2206 81 N 12 2 W 35 2217 28 2277 27 2337 65 2397 45 2458 09 2519 92 2579 77 2640 45 2701 63 N 471.09 W 2267 11 N 12 0 W 29 N 481.35 W 2327 61 N 11 56 W 32 N 491.17 W 2388 37 N 11 52 W 67 N 500.57 W 2449 36 N 11 48 W 37 N 509.32 W 2510 58 N 11 42 W 11N 517.98 W 2571.81 N 11 37 W 34 N 527.18 W 2632.66 N 11 33 W 05 N 535.59 W 2693.83 N 11 28 W 47 N 543.10 W 2755.52 N 11 22 W 0 62 2762 75 N 550 32 W 2817.02 N 11 16 W 82 2823 44 2882 33 2937 14 2989 26 3036 23 3081 46 3122 14 3163 59 3204 20 N 557 27 N 565 96 N 572 O1N 578 78 N 583 34 N 584 35 N 583 15 N 581 25 N 580 87 W 2877.79 N 11 11W 63 W 2937.25 N 11 6 W 70 W 2993 25 N 11 2 W 53 W 3044 49 N 10 57 W 09 W 3092 25 N 10 52 W 50 W 3136 29 N 10 44 W 48 W 3176 40 N 10 35 W 91 W 3216 23 N 10 25 W 25 W 3256 36 N 10 16 W 0 43 3245.88 N 578 57 W 3297 04 N 10 6 W 0 32 3287.87 N 576 54 W 3338 04 N 9 57 W 0 30 3329.97 N 574 14 W 3379 10 N 9 47 W 0 37 3372.20 N 571 82 W 3420 34 N 9 37 W 0 O0 3413.41 N 569 46 W 3460 58 N 9 28 W 0 O0 3454.24 N 567 O1 W 3500 46 N 9 19 W ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE: 8-NOV-g2 PAGE 4 DATE OF SURVEY: 2-NOV-g2 KELLY BUSHING ELEVATION: 50.80 ET INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 -50.80 0 0 99 949 19 0 14 96 1949 16 0 50 72 2948 92 I 26 36 3945 56 9 46 54 4863 74 32 55 ENGINEER: SCHWARTZ 0.00 1000.00 999 2000.00 1999 3O00.0O 2999 4000.00 3996 5000.00 4914 6000.00 5726 7000.00 6536 8000.00 7337 9000.00 8128 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOL/TH EAST/WEST DIST. AZIMLrrH FEET DEG/IOO FEET FEET FEET DEG MIN 99 5676 29 6485 11 7286 53 8077 19 36 35 49 36 24 31 37 4 73 37 53 0 O0 N 0 OE S 1 42 W -3 N 77 42 E -6 N 46 53 E 0 N 11 17 W 63 N 16 8 W 438 N 11 55 W 1020 N 13 19 W 1606 N 10 45 W 2204 N 6 53 W 2815 75 94 01 68 75 02 91 68 72 0 O0 0 O0 0 O0 0 01 2 41 0 72 0 53 0 36 0 38 0 62 0 O0 N 3 5 3 68 431 999 1574 2158 2762 0 O0 E 75 S 0 96 S 6 76 N 22 97 N 26 96 N 76 5O N 207 63 N 326 29 N 460 75 N 550 0 O0 N 0 0 E 31E 3 46 E 8 35 E 22 24 E 73 99 W 438 33 W 1020 32 W 1608 20 W 2206 32 W 2817 76 S 4 47 E 79 S 47 19 E 66 N 80 28 E 79 N 20 50 E 77 N 10 6 W 77 N 11 43 W 08 N 11 42 W 81 N 12 2 W 02 N 11 16 W 10000.00 8998.40 8947.60 24 50 10500.00 9452.77 9401.97 24 9 N 2 27 E 3296.86 N 3 25 E 3500.44 0.43 O. O0 3245.88 N 578.57 W 3297.04 N 10 6 W 3454.24 N 567.01 W'3500.46 N 9 19 W ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE' 8-NOV-g2 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 50.80 150.80 250.80 350.80 450.80 550.80 650.80 750.80 850.80 PAGE 5 DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 O0 50 80 150 80 250 80 350 80 450 80 550 80 650 80 750 81 850 81 950.81 -50 80 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 950 80 900 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 0 N 0 0 E 0 I N 36 39 E 0 6 S44 I E 0 7 S 19 42W 0 8 S 150 E 0 24 S 22 45 E 019 S 3 2 E 0 18 S 0 14 W 0 18 S 3 35W 0 18 S 3 33W 1050.81 1050 1150.81 1150 1250.81 1250 1350 81 1350 1450 81 1450 1550 82 1550 1650 82 1650 1750 82 1750 1850 80 1000 80 1100 80 1200 80 1300 80 1400 8O '1500 80 1600 80 1700 83 1850.80 1800 1950.84 1950 80 1900 O0 2050 85 2050 80 2000 O0 80 2100 O0 80 2200 O0 80 2300 O0 80 2400 O0 80 2500 O0 80 2600 O0 80 2700 O0 80 2800 O0 016 S 3 47 W 0 10 S 6 3 W 0 14 S 10 40 E 0 21 S 33 19 E 0 17 S 60 33 E 0 20 S 58 29 E 0 17 S 69 18 E 0 31 S 67 49 E 0 35 S 78 24 E 0 42 N 88 49 E 2150 2250 2350 2450 2550 2650 2750 2851 0 51 N 79 24 E 0 45 N 79 33 E 0 37 N 89 23 E 0 39 S 79 41 E 0 40 S 85 21 E 0 52 N 86 49 E I 7 N 72 17 E I 54 N 45 44 E I 56 N 34 2 E 1 36 N 38 53 E 85 2150 86 2250 87 2350 87 2450 89 2550 93 2650 98 2750 03 2850 FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 01 -0 08 -0 21 -0 41 -0 89 -1 50 -2 01 -2 55 -3 06 -3.54 -3.92 -4.27 -4 79 -5 23 -5 58 -5 89 -6 19 -6 62 -6 90 -6 97 -6 92 -6 99 -7 30 -7 64 -7 87 -7 86 -6 81 -4 55 -2 37 0 O0 0 46 0 13 0 O0 0 15 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 20 0 O0 0 04 0 O0 0 O0 0 18 0 01 0 01 0 O3 0 29 0 18 0 16 0 O3 0 2O I O5 0 64 0 O9 0 23 0 O0 N 0 01N 0 06 S 0 19 S 0405 0 87 S 1 45 S I 97 S 2 525 3055 3 53 S 3 92 S 4 28 S 4 77 S 5 145 5435 5 665 5 885 6 155 6 26 S 6 10 S 5 81 S 5 69 S 5 82 S 5 985 5 99 S 5 715 4 27 S I 62S 0 89 N 0 O0 E O01E 0 13 E 0 13 E 009 E 024 E 041E 041E 040E 0 36 E 033E 0 31E 0 30E 051E 0 92E 137 E I 85E 241E 3 35 E 4 41E 5 75E 7 15E 8 33 E 9 43 E 10 52 E 11 83 E 13 47 E 15 75 E 17 85 E 19 65 E 0.00 N 0 0 E 0 01 N 31 0 E 14 S 65 9 E 23 S 34 41E 41 S 12 49 E 90 S 15 33 E 51 S 15 55 E 02 S 11 52 E 55 S 8 57 E 07 S 6 48 E 9 10 11 12 13 14 16 17 19 3 55 S 5 17 E 3 93 S 4 3O E 4 29 S 3 57 E 4 8O S 6 9 E 5 23 S 10 10 E 5 60 S 14 11E 5 95 S 18 8 E 6 35 S 22 18 E 7 O0 S 28 34 E 7 66 S 35 9 E · 8 39 S 43 19 E 21 S 50 52 E 09 S 55 38 E 08 S 58 20 E 10 S 60 23 E 26 S 63 8 E 64 S 67 I E 32 S 74 50 E 92 S 84 48 E 67 N 87 24 E 2951 07 2950.80 2900.00 3051 3151 3251 3351 3451 3551 3651 3752 3852 10 3050.80 3000.00 14 3150.80 3100.00 19 3250.80 3200.00 25 3350.80 3300.00 30 3450.80 3400.00 36 3550.80 3500.00 53 3650.80 3600.00 09 3750.80 3700.00 87 3850.80 3800.00 1 29 N 45 14 E I 25 N 46 18 E I 51 N 35 14 E 1 56 N 22 1E 1 53 N 17 4 E 1 54 N 16 12 E 2 6 N 14 40 E 4 44 N 2 6 E 6 53 N 3 39 W 7 22 N 4 34 W -0 70 0 71 2 46 5 10 7 99 10 95 14 O0 19.47 29.90 42.33 0 O0 0 O0 0 56 0 36 0 O0 0 O0 0 80 2 87 0 68 0 49 2 89 N 4 62 N 6 71N 9 65 N 12 75 N 15 92 N 19 16 N 24 83 N 35 36 N 47 81 N 21 45 E 23 27 E 25 13 E 26 67 E 27 77 E 28 70 E 29 61 E 3O 34 E 30 07 E 29 18 E 21 65 N 82 20 E 23 26 28 30 32 35 39 46 56 73 N 78 46 E 01 N 75 3 E 37 N 7O 7 E 56 N 65 20 E 82 N 6O 59 E 27 N 57 5 E 21 N 5O 42 E 42 N 40 22 E O1 N 31 24 E ARCO ALASKA INC. P1-20 POINT MC INTYRE NORTH SLOPE, ALASKA COMPUTATION DATE' 8-NOV-92 PAGE 6 DATE OF SURVEY- 2-NOV-92 KEL_LY BUSHING ELEVATION' 50.80 ET INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DF_PTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 8 43 N g 17 W O0 10 51 N 11 54 W O0 13 47 N 10 51 W O0 16 55 N 16 6 W O0 20 6 N 17 9 W O0 21 46 N 17 10 W O0 25 36 N 16 26 W O0 27 42 N 16 25 W O0 28 36 N 16 21W O0 31 52 N 16 4 W 3953.84 3950.80 3900 O0 4055.34 4050.80 4000 4157.69 4150.80 4100 4261.38 4250.80 4200 4366 87 4350.80 4300 4473 92 4450.80 4400 4582 98 4550.80 4500 4695 30 4650.80 4600 4808 47 4750.80 4700 4924 47 4850.80 4800 ENGINEER' SCHWARTZ 5043 21 4950 80 4900.00 32 59 41 5050 19 5150 81 5250 40 5350 74 5450 50 5550 18 5650 80 5000.00 33 17 80 5100.00 36 6 80 5200.00 36 44 80 5300.00 36 37 80 5400.00 36 16 80 5500.00 35 58 80 5600.00 36 17 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5162 5284 5408 5533 5657 5781 5905 6029 6153 56 22 73 57 95 3O 122 56 155 81 193 66 236 79 287 55 340.14 398.50 N 16 I W N 15 38 W 526 N 13 40 W 595 N 13 27 W 669 N 12 7 W 744 N 11 34 W 817 N 11 8 W 890 N 11 2 W 963 N 11 55 W 1037 N 11 34 W 1111 I 81 I 95 3 31 4 06 I 99 2 41 4 37 0 25 2 46 I 61 61 64 N 78 66 N 100 O1N 126 57 N 158 62 N 195 11N 236 74 N 285 78 N 336 61N 393 04 N 27.59 E 24 23 E 2O 13 3 7 19 34 49 65 82 17 E 102 69 E 127 80 E 158 49 W 195 98 W 237 46 W 287 38 W 340 73 W 398 67 53 N 24 7 E 31 N 17 7 E 02 N 11 24 E 31 N 6 10 E 67 N 1 22 E 25 N 2 12 W 58 N 4 49 W 86 N 6 53 W 21 N 8 21W 50 N 9 30 W 64 5750 80 5700.00 36 32 96 5850 80 5800.00 36 23 462 10 56 78 97 15 98 86 60 66 47 0 24 2 32 1 85 0 54 0 84 0 53 0 85 I 07 0 27 0 44 454 55 N 516 584 656 728 801 872 944 1016 1089 83 48 W 462 15 N 10 24 W 92 N 101 20 N 118 52 N 135 94 N 152 27 N 167 74 N 182 18 N 196 77 N 210 08 N 226 36 W 526 62 W 596 99 W 67O 67 W 744 73 W 818 19 W 891 06 W 964 97 W 1038 04 W 1112 76 N 11 6 W 12 N 11 29 W 45 N 11 42 W 76 N 11 50 W 64 N 11 49 W 56 N 11 47 W 32 N 11 44 W 43 N 11 43 W 29 N 11 44 W 6278 18 5950.80 5900 O0 36 20 6402 6526 6648 6771 6893 7018 7142 7267 7391 26 6050.80 6000 O0 6150.80 6100 70 6250 80 6200 03 6350 80 6300 97 6450 80 6400 03 6550 80 6500 37 6650 80 6600 05 6750 80 6700 89 6850 80 6800 O0 36 2O O0 35 38 O0 35 16 O0 35 8 O0 36 6 O0 36 27 O0 36 32 O0 36 44 O0 36 52 N 11 25 W 1185 11 N 11 37 W 1258 N 11 19 W 1331 N 11 12 W 1402 N 11 28 W 1472 N 12 31W 1544 N 13 20 W 1617 N 13 23 W 1691 N 13 41W 1765 N 13 39 W 1840 53 36 43 85 31 59 31 6O 14 0 38 0 25 0 74 0 56 0 39 0 91 0 23 0 52 0 27 0 19 1161.31 N 240 62 W 1185.97 N 11 42 W 1233.30 N 255 1304.71N 269 1374.45 N 283 1443 55 N 297 1513 52 N 312 1585 04 N 328 1656 94 N 345 1729 34 N 363 1801 95 N 380 27 W 1259.44 N 11 42 W 75 W 1332.31 N 11 41 W 64 W 1403 41 N 11 40 W 41 W 1473 86 N 11 38 W 21W 1545 38 N 11 39 W 78 W 1618 78 N 11 43 W 82 W 1692 64 N 11 47 W 23 W 1767 08 N 11 52 W 94 W 1841 78 N 11 56 W 7516.99 6950 80 6900 O0 36 57 7642.12 7050 7767.09 7150 7892 02 7250 8017 15 7350 8142 60 7450 8268 44 7550 8394 68 7650 8521 31 7750 8647.70 7850 80 7000 O0 36 56 80 7100 O0 36 51 80 7200 O0 36 51 80 7300 O0 37 5 80 7400 O0 37 14 80 7500 O0 37 30 80 7600 O0 37 42 80 7700.00 37 57 80 7800.00 37 29 N 13 27 W 1915.11 N 13 2 W 1990.17 N 12 22 W 2065.00 N 11 27 W 2139 82 N 10 38 W 2215 02 N 9 48 W 2290 75 N 9 14 W 2367 14 N 8 33 W 2444 18 N 7 54 W 2521 85 N 8 51W 2599 14 0 25 0 36 0 53 0 46 0 40 0 59 0 29 0 61 0 51 0 46 1875 02 N 398 53 W 1916 91 N 12 0 W 1948 2021 2094 2168 2242 2318 2394 2471 2547 23 N 415 34 N 432 63 N 447 45 N 462 99 N 475 34 N 488 45 N 500 35 N 511 83 N 522 79 W 1992 30 W 2067 69 W 2141 10 W 2217 54 W 2292 11W 2369 09 W 2446 12 W 2523 39 W 2600 11 N 12 3 W 05 N 12 4 W 94 N 12 4 W 15 N 12 2 W 85 N 11 58 W 16 N 11 53 W 11 N 11 48 W 65 N 11 41W 83 N 11 35 W ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE: 8-NOV-92 PAGE 7 DATE OF SURVEY: 2-NOV-g2 KELLY BUSHING ELEVATION: 50.80 ET ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8774 04 7950 80 7900 O0 37 53 N 7 39 W 2676 32 8901 9028 9~53 9276 9393 9507 9618 9728 9837 24 8050 80 8000 18 8150 80 8100 76 8250 80 8200 09 8350 80 8300 27 8450 80 8400 28 8550 80 8500 65 8650.80 8600 20 8750.80 8700 O0 38 18 N 6 39 W 2754 O0 37 42 'N 7 I W 2832 O0 36 37 N 7 34 W 2908 O0 33 13 N 7 0 W 2979 O0 29 40 N 6 26 W 3040 O0 27 58 N 3 46 W 3094 O0 24 25 N 0 59 E 3143 O0 24 6 N 2 3 E 3187 78 8850.80 8800.00 24 16 N 2 16 E 3231 86 97 87 23 21 80 27 13 01 0.89 2624 23 N 533 49 W 2677 90 N 11 29 W 0.45 2702 0 85 2779 I 25 2855 3 79 2925 2 29 2985 4 49 3040 2 76 3089 0 51 3133 0 39 3178 23 N 543 89 N 552 24 N 562 06 N 571 70 N 578 19 N 583 15 N 584 85 N 583 64 N 581 19 W 2756 41W 2834 05 W 2910 13 W 2980 16 W 3041 33 W 3095 44 W 3143 09 W 3187 3O W 3231 29 N 11 22 W 24 N 11 14 W O3 N 11 8 W 29 N 11 3 W 17 N 10 58 W 65 N 10 52 W 95 N 10 43 W 64 N 10 32 W 36 N 10 22 W 9947 60 8950 80 8900 O0 24 36 N 2 15 E 3275.42 10057 76 9050 80 9000 O0 24 53 N 2 48 E 3320.62 10167 98 9150 80 9100 O0 25 0 N 3 19 E 3365.84 10278 37 9250 80 9200 O0 24 55 N 3 3 E 3411.46 10388 25 9350 80 9300 O0 24 9 N 3 25 E 3455.90 10497 84 9450 80 9400 O0 24 9 N 3 25 E 3499.58 10500 O0 9452 77 9401 97 24 9 N 3 25 E 3500.44 0 39 3223.98 N 579.46 W 3275 64 N 10 11 W 0 30 3270.15 N 577.46 W 3320 74 N 10 1 W 0 52 3316.43 N 574.92 W 3365 89 N 9 50 W 0 54 3363.12 N 572.30 W 3411 47 N 9 39 W 0 O0 3408.61N 569.74 W 3455 90 N 9 29 W 0 O0 3453.35 N 567.07 W 3499 60 N 9 20 W 0 O0 3454.24 N 567.01W 3500 46 N 9 19 W ARCO ALASKA INC. Pi -20 POINT MCINTYRE NORTH SLOPE, ALASKA MARKER LAST READING GCT TD COMPUTATION DATE: 8-NOV-g2 PAGE 8 DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 ET ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1384' FSL & 908' FEE, SEC16 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10371.10 9335.16 9284.36 3401.56 N 570.19 W 10500.00 9452.77 9401.97 3454.24 N 567.01W ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA MARKER LAST READING GCT 'ID COMPUTATION DATE: B-NOV-92 PAGE 9 DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1384' FSL & 908' FEL, SEC16 T12N R14E MEASURED DEPTH I'VD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10371.10 9335.16 9284.36 3401.56 N 570.19 W 10500.00 9452.77 9401.97 3454.24 N 567.01W FINAL WF[I LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10S00.00 9452.77 9401.97 HORIZONTAL DEPARTURE DISTANCE AZI~J1-H FEET DEG MIN 3500.46 N 9 19 W DIRECTIONAL SURVEY FI~L,~ ~O~NTRY ~ UNIT ARCO ALASKA INC. 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I . . . .?F~F"~ ...... ¢": "'" ..... * : : -.-~.+-b+q'-~--++-r-'?-~--!--! ...... ~'"~"i"i ..... ?'i'"?'! .... hi"I"! ...... !"*?'?'i ..... h'?'*?""i'"h'?'i ...... h'h'?"~ ...... ]'"?'i"!'""i"'h'?"~ ...... h'?'?"~" r'r'*?"r'~ ...... ~'"; ....... :'""'; ..... ?": ,"~d"I'~?'!"~'~'~ ~d"~ .... ~- ~ ~=~ ====hH-~ q~'~"~!'"~ ...... h'~-'~--'~ ...... h~--+'-h?"?i'+'; '-~, ........... . *-, '-'~'"~'"~'"~: ,, ................. ::: FINAL WELL REPORT PRUDHOE BAY DRILLING GROUP POINT McINTYRE P1-20 NORTH SLOPE, ALASKA OCTOBER 13, 1992 TO OCTOBER 28, 1992 THE INFORMATION, INTERPRETATIONS, RECOMMENDATIONS, OR OPINIONS CONTAINED HEREIN ARE ADVISORY ONLY AND MAY BE REJECTED. CONSULTANT DOES NOT WARRANT THEIR ACCURACY OR CORRECTNESS. NOTHING CONTAINED HEREIN SHALL BE DEEMED TO BE INCONSISTENT WITH, NOR EXPAND, MODIFY OR ALTER CONSULTANT'S OBLIGATION OF PERFORMANCE AS PROVIDED FOR IN A WRITTEN AGREEMENT BETWEEN THE PARTIES, OR IF NONE, IN CONSULTANT'S MOST RECENT PRICE LIST. EXPLORATION LOGGING OF USA, INC. COMPILED BY: DOUG FORSTER RALPH WINKELMAN APPROVED BY: LARRY SHIELDS MICROFILMED TABLE OF CONTENTS PAGE INTRODUCTION ............................................ 1 SUMMARY OF DATA ......................................... 2 METHODS OF: ............................................. 3 MUDLOG .......................................... 3 DRILL DATA ACQUISITION .......................... 3 COMMUNICATIONS .................................. 3 SAMPLING PROCEDURES AND INTERVALS ............... 3 FORMATION EVALUATION WEST SAK LITHOLOGY ............................... 4 DRILL AND GAS DATA ...................... 5 OIL AND GAS SHOWS ....................... 5 HUE SHALES (K10,K5-SHALE WALL, HRZ,) LITHOLOGY ............................... 6 DRILL AND GAS DATA ...................... 6 OIL AND GAS SHOWS ....................... 6 KALUBIK AND KUPARUK LITHOLOGY ............................... 7 DRILL AND GAS DATA ...................... 7 OIL AND GAS SHOWS ....................... 8 MILUVEACH LITHOLOGY ............................... 8 DRILL AND GAS DATA ...................... 8 OIL AND GAS SHOWS ....................... 8 APPENDIX I. SHOW REPORTS II. BIT RECORD INTRODUCTION THE P1-20 WELL IS ONE OF A SERIES OF POINT McINTYRE DELINEATION WELLS, DRILLED ON THE PM1 PAD, APPROXIMATELY 12 MILES NORTH WEST OF PRUDHOE BAY, ALASKA. COORDINATES FOR THE SURFACE LOCATION OF THE WELL ARE: 1384' FSL & 908' FEL, IN SECTION 16, TlZN, R14E UMIAT MERIDIAN. PROPOSED BOTTOM HOLE COORDINATES WERE: 632' FNL & 1572' FEL, IN SECTION 16, T12N, R14E UMIAT MERIDIAN. THE MAIN OBJECTIVE OF THIS WELL WAS TO TEST THE KUPARUK RIVER FORMATION, A LOWER CRETACEOUS AGE MEMBER OF THE UGNURAVIK GROUP, AT A PROJECTED DEPTH OF 8600' SUB SEA TRUE VERTICAL; THROUGH, THE RECOVERY OF LOW INVASION CORES OVER THE ZONE OF INTEREST AND BY ELECTRIC LOG ANALYSIS UPON THE COMPLETION OF DRILLING. PROJECTED TARGET (KUPARUK RIVER) COORDINATES WERE: 903' FNL & 1517' FEL, IN SECTION 16, T12N, R14E UM. THE PROPOSED TARGET WAS REACHED BY DRILLING A DEVIATED HOLE; THROUGH THE USE OF DIRECTIONAL DRILLING TOOLS AND TECHNIQUES, SUCH THAT THE PROPOSED BOTTOM HOLE LOCATION WOULD BE NORTHWEST AT AN AZIMUTH OF 12.5 DEGREES AND WITH A DEPARTURE OF 3300', WITH RESPECT TO SURFACE LOCATION. THE WELL PROGRAM WAS DESIGNED FOR THE KICK-OFF TO START AT ABOUT 3500' MD AND TO GRADUALLY BUILD ANGLE TO 37.7 DEGREES FROM TRUE VERTICAL AT ABOUT 5250' TRUE VERTICAL DEPTH. IT WAS PROPOSED TO HOLD THE ANGLE UNTIL 8706', AT WHICH POINT THE ANGLE WOULD BE DROPPED TO A FINAL HOLE ANGLE OF 20 DEGREES FROM VERTICAL. THE WELL PROGRAM WAS DESIGNED TO SET 9-5/8 INCH CASING JUST ABOVE THE TOP OF THE KUPARUK AND TO CHANGE OUT THE FRESH WATER BASED DRILLING MUD TO LVT 200, A MINERAL OIL BASED DRILLING FLUID WITH LESS THAN 2% WATER CONTENT, DESIGNED FOR THE RETRIEVAL OF LOW INVASION CORES. THE PROJECTED STRATIGRAPHIC SEQUENCE PENETRATED BY THIS HOLE INCLUDED THE PERMAFROST, T-3, K-15, WEST SAK, K-10, HRZ, KALUBIK, AND KUPARUK RIVER FORMATIONS WITH PROPOSED FINAL WELL T.D. IN THE LOWER CRETACEOUS MILUVEACH FORMATION. -1- SUMMARY OF PERTINENT DATA WELL NAME: API NUMBER: OPERATOR: PARTNERS: CONTRACTOR: LOCATION: POINT McCINTYRE P1-20 50-029-22288 PRUDHOE BAY DRILLING GROUP ARCO ALASKA, BP EXPLORATION, AND EXXON POOL/ARCTIC ALASKA DRILLING POOL RIG #? 1384' FSL, 908' FEL SEC 16, T12N, R14E UMIAT MERDIAN ELEVATION: CASING: DATE SPUDDED: DATE TOTAL DEPTH REACHED: FINAL TOTAL DEPTH: CONVENTIONAL CORES: FORMATION TESTS: HYDROCARBON SHOWS: COMPANY GEOLOGISTS: EXLOG GEOLOGISTS: FINAL WELL STATUS: GROUND LEVEL 9' ABOVE SEALEVEL ROTARY KELLY BUSHING 43' ABOVE MEAN 9.625" AT 9638' RKB 7.00" AT 10500' RKB OCTOBER 7, 1992 OCTOBER 28, 1992 10500' MD, 9452' TVD CORE #1 9646' - 9705' CORE #2 9705' - 9764' CORE #3 9764' - 9823' CORE #4 9823' - 9882' CORE #5 9882' - 9941' CORE #6 9941' - 10000' CORE #7 10000'- 10089' CORE #8 10089'- 10178' CORE #9 10178'- 12237' NONE RUN AT THIS TIME SEE SHOW REPORTS - APPENDIX II. JIM GONSIEWSKI, ARCO ALASKA KEVIN FRANK, ARCO ALASKA BOB HUNTER, BP EXPLORATION DOUG FORSTER, RALPH WINKELMAN E-LOGS AND RUN 7" LINER TO T.D. -2- METHODS GEOLOGIC AND DRILLING DATA WAS COLLECTED AT THE WELLLSITE USING EXLOG'S DRILL MONITOR SYSTEM (DMS). THE SYSTEM IS A COMPUTER BASED DATA COLLECTION UNIT, USED IN ACQUISITION, COMPILATION AND OUTPUT OF DATA. ADDITIONAL LITHOLOGIC AND HYDROCARBON EVALUATION WAS PROVIDED BY EXLOG'S ONSITE GEOLOGISTS. METHODS OF ANALYSIS USED FOR EVALUATION ARE PRESENTED IN EXLOG'S MANUAL "MUDLOGGING: PRINCIPLES AND INTERPRETATIONS" (MS-196). MUDLOG THE MUDLOG FORMAT WAS PREVIOUSLY ESTABLISHED ON FORMER POINT McCINTYRE WELLS LOGGED BY EXLOG. DATA DISPLAYED ON THE LOG INCLUDES: LITHOLOGY, RATE OF PENETRATION, TOTAL GAS, CUTTINGS GAS, CHROMATOGRAPH DATA, RESISTIVITY AND GAI~A RAY DATA WAS IMPORTED FROM AN/fl]RILL AT THE END OF EACH BIT RUN. TOTAL GAS, RATE OF PENETRATION, CUTTINGS GAS AND GA~ RAY ARE PLOTTED LINEARLY, WHILE ALL OTHER PARAMETERS ARE PLOTTED LOGARITHMICALLY. LOGS WERE PLOTTED AS Z INCHES PER 100 FEET (1:600), WITH THE EXCEPTION OF THE PRESSURE DATA LOG (2 INCHES PER 500 FEET/l:3000). DRILL DATA DRILLING DATA MONITORED INCLUDED: RATE OF PENETRATION (ROP) USING THE KELLY HEIGHT SYSTEM, ROTARY SPEED, HOOKLOAD, WEIGHT ON BIT, TORQUE (MINIMUM, MAXIMUM, AND AVERAGE), MUD FLOW IN AND OUT, MUD TEMPERATURE IN AND OUT, STANDPIPE PRESSURE, CASING PRESSURE, PUMP STROKES, AND ALL PITS WERE MONITORED. ALSO THREE H2S STATIONS WERE MONITORED AT ALL TIMES. THIS DATA WAS PLOTTED ON THE LOGS AS WELL AS BEING DISPLAYED ON REMOTE TERMINALS. COMMUNICATION EXLOG PROVIDED ONSITE AND OFF LOCATION REMOTE TERMINALS FOR THE DISPLAY OF ALL DRILLING PARAMETERS. THERE WAS A RADIO MODEM CONNECTION WITH A REMOTE TERMINAL IN THE RADIO ROOM OFF LOCATION IN THE AUDI#2 CAMP, A REMOTE TERMINAL IN THE GEOLOGIST'S OFFICE AT THE WELLSITE, AS WELL AS A REMOTE TERMINAL IN THE COMPANY MAN'S OFFICE. AN EXPLOSION PROOF DRILL MONITOR (HAD) WAS PROVIDED FOR THE DRILLER ON THE RIG FLOOR. SAMPLING SAMPLES WERE COLLECTED AS PER THE DIRECTIONS RECIEVED FROM BOB DAWSON IN THE ARCO ALASKA OFFICES. THREE WET AND FIVE DRY SAMPLES WERE COLLECTED. 6467' - 8940' MD 8940' - TD 30 FOOT SAMPLE INTERVALS 10 FOOT SAMPLE INTERVALS ALL SAMPLES WERE SHIPPED TO THE BAYVIEW GEOLOGIC FACILITY WAREHOUSE IN ANCHORAGE, IN CARE OF M.V. STANFORD. A COMPLETE LISTING OF SAMPLE SHIPMENTS CAN BE FOUND IN THE APPENDIX. -3- FORMATION EVALUATION COMMENCE LOGGING AT 1930 HOURS, OCTOBER 13, 1992 AT 6101 FEET TVD (6467 FEET MI)) IN THE LATE CRETACEOUS. ALL DEPTHS, UNLESS OTHERWISE SPECIFIED, ARE FROM K.B. WHICH WAS 52 FEET ABOVE SEA LEVEL. ALL FORMATION TOPS ARE UNCONFIRMED AND APPROXIMATE. WEST SAK INTERVAL LITHOLOGY THE WEST SAK 6660' - 8340' TVD (7160 - 9264' MD) THE WEST SAK IN THE P1-20 WELL CONSISTED OF THREE SOMEWHAT DIFFERENT ZONES. THE FIRST, OR UPPER, ZONE ENCOUNTERED WAS FROM 6660 TO 7020' TVD (7160' - 7595' MD). THIS ZONE CONTAINED A HIGH PERCENTAGE OF SANDSTONE, UNCONSOL- IDATED SAND AND CONGLOMERATE, WITH ABUNDANT SILT AND CLAY MATRIX. THE SAND- STONE WAS VERY FINE TO FINE GRAINED QUARTZITIC SANDSTONE, WITH COMMON CALCITE CEMENT. UNCONSOLIDATED COARSE GRAINED QUARTZ SAND AND LITHIC PEBBLES WERE ALSO VERY ABUNDANT IN THIS ZONE. ABUNDANT SILT AND CLAY WERE ALSO PRESENT PRESUMABLY AS MATRIX FOR THE UNCONSOLIDATED SAND AND CONGLOMERATE. COMMON TO ABUNDANT SHALE, SILTSTONE, AND MUDSTONE WERE ALSO OBSERVED. TRACES OF PYRITE AND WHITE VOLCANIC TUFF WERE PRESENT IN THIS INTERVAL. FROM 7020' TO 8345' TVD (7595' - 9270' MD) THE WEST SAK WAS COMPOSED OF A MEDIUM GRAY TO GRAY BROWN CARBONACEOUS SILSTONE AND SHALE. COMMON SANDY SILSTONE AND SANDY SHALES WERE ALSO OBSERVED. WITH OCCASIONAL SAND AND SANDSTONE INTERBEDS. UNCONSOLIDATED LITHIC AND QUARTZ GRAINS AND BROKEN PEBBLES WERE PRESENT THROUGHOUT THIS MIDDLE ZONE OF THE WEST SAK, BUT NOT TO THE DEGREE SEEN IN THE UPPER INTERVAL. TRACE AMOUNTS OF PYRITE AND VOLCANIC TUFF WERE COMMON THROUGHOUT THIS INTERVAL. RARE INOCERAMUS PRISMS AND COAL WERE SEEN BELOW 7300' TVD (7960' MD). MORE COMMON INOCERAMUS PRISMS WERE NOTICED AT 8530' TVD (9485' MD), BUT THE CHARACTERISTIC "FLOOD" OF INOCERAMI WAS NOT OBSERVED IN CUTTINGS SAMPLES. FROM 8345' TO 8460' TVD (9265' - 9400' MD) A FAIRLY DISTINCT SILTY SANDSTONE INTERBED WAS ENCOUNTERED, WITH SHALEY INTERBEDS ABOVE AND BELOW THE SANDSTONE. THE S/~NDSTONE WAS LIGHT GRAY TO BROWN OIL-STAINED AND COMPOSED OF FINE GRAINED QUARTZ WITH ABUNDANT SILTY MATRIX AND POSSIBLE SIDERITE CEMENT. VISIBLE POROSITY IN THIS S~DMTONE WAS ONLY FAIR, DUE TO THE LARGE AMOUNTS OF MATRIX AND CEMENTING AGENTS. IT SHOULD BE NOTED HERE THAT IT IS UNCLEAR, AT THIS POINT IN TIME, IF THIS SANDSTONE INTERVAL IS PART OF THE WEST SAK OR A DIFFERENT FORMATION ALTOGETHER (POSSIBLY STUMP ISLAND SANDS). -4- DRILL RATE AND GAS DATA DRILL RATES IN THE WEST SAK RANGED FROM 15 TO 500 FEET PER HOUR. IN THE UPPER ZONE (SAND/CONGLOMERATE}, RATES RANGED FROM 20 TO 500 FEET PER HOUR WITH AN AVERAGE RATE OF PENETRATION OF APPROXIMATELY 100 FEET PER HOUR. IN THE MIDDLE ZONE, CHARACTERIZED BY SILTSTONE AND SHALE, DRILL RATES RANGED FROM 15 TO 200 PER HOUR. RATES IN THE MIDDLE WEST SAK, HOWEVER, GENERALLY SHOWED LITTLE DEVIATION FROM A 45 FOOT PER HOUR AVERAGE. THE LOWER WEST SAK (UN-NAMED SANDSTONE?), RANGED IN DRILL RATES FROM 10 TO 200 FEET PER HOUR, AVERAGING 50 FEET PER HOUR. LITTLE SLIDING (NON-ROTARY DRILLING) WAS DONE IN THE WEST SAK IN ORDER TO OBTAIN OR KEEP THE PROPER HOLE INCLINATION AND AZIMUTH. AREAS WHERE SLIDING WAS DONE EXHIBITTED MORE IRREGULAR DRILL RATES, BUT AVERAGE DRILL RATES WERE NOT SIGNIFICANTLY DIFFERENT FROM THOSE PREVIOUSLY MENTIONED. DITCH GAS RANGED FROM 15 TO 1875 UNITS IN THE WEST SAK, AND AVERAGED 150 UNITS. HIGHER GAS READINGS OCCURRED IN SEVERAL AREAS OF THE UPPER WEST SAK DUE TO THE SOMEWHAT UNEXPECTED PRESENCE OF MODERATE AMOUNTS OF HYDROCARBONS. A PEAK GAS READING OF 1875 UNITS WAS EXPERIENCED IN THE LOWER UN-NAMED SANDSTONE (STUMP ISLAND?) AND WAS ACCOMPANIED BY A MODERATE OIL SHOW. HIGH C1 THROUGH C4 WAS PRESENT THROUGHOUT MUCH OF THE SECTION, WITH ONLY OCCASIONAL ABSENCE OF C4 IN AREAS OF LOW TOTAL GAS READINGS. OIL AND GAS SHOWS TRACE VERY DULL YELLOW TO ORANGE SAMPLE FLUORESCENCE AND A VERY SLOW STREAMING DULL YELLOW CUT FLUORESCENC WAS PRESENT THROUGHOUT THE ENTIRE WEST SAK. TRACE TO FAIR AMOUNTS OF DARK BROWN "TARRY" OIL WAS NOTICED IN THE SAMPLES BELOW 6800 FEET TVD (7330 FEET MD). THIS OIL WAS SEEN STAINING SANDSTONES AND SILTSTONES WITH POOR VISIBLE POROSITY AND THE SHOW WAS RATED FAIR. HOWEVER, THE PRESENCE OF OIL IN THIS ZONE GENERATED ENOUGH INTEREST TO JUSTIFY A MEMORY LOG PASS BY THE ANADRIL MWD TOOL. THE UN-NAMED SANDSTONE, IN THE LOWER WEST SAK, EXHIBITTED BRIGHTER SAMPLE FLUORESCENCE AND A MILKY YELLOW TO BLUE WHITE CUT FLUORESCENCE. NO VISIBLE CUT WAS SEEN IN THIS INTERVAL, POSSIBLY INDICATING A CONDENSATE OIL OR GAS CAP SHOW. TWO SHOW REPORTS WERE DONE FOR THIS INTERVAL; ONE FOR THE WEST SAK SHALES, SILTSTONE, AND UNCONSOLIDATED LITHICS, AND ONE FOR THE UN- NAMED SANDSTONE (SEE APPENDIX FOR DETAILS). -5- HUE SHALE SECTION (K10, K5, HRZ) LITHOLOGY THE HUE SHALE CONTAINING THE K-10, K-5, AND HRZ WAS ENCOUNTERED AT APPROX- IMATELY 8460' TVD (9410' MD) AND CONTINUED TO 8647' TVD (9615' MD). IT CONSISTED FIRST OF THE K-10 ZONE, WHICH WAS FROM APPROXIMATELY 8460 TO 8545' TVD (9410'- 9500' MD). THE K-10 WAS PREDOMINATELY A MEDIUM GRAY BROWN CARBONACEOU SILTY SHALE, WITH VERY ABUNDANT BLUE GRAY AND WHITE VOLCANIC TUFFS. MINOR SANDY SILTSTONE AND SANDY SHALE INTERVALS WERE ALSO OBSERVED. MINOR INOCERAMUS PRISMS AND PYRITE WERE ALSO PRESENT. THE K-5 AND HRZ WAS ENCOUNTERED AT APPROXIMATELY 8545' TVD (9500' MD), AND CONTINUED TO 8645' TVD (9615' MD). THE HRZ WAS CHARACTERIZED BY VERY FISSILE DARK GRAY SHALES (PAPER SHALE) WITH MINOR SILTSTONE INTERVALS NEAR ITS BASE. BOTH THE K-10 AND HRZ ARE VERY ORGANIC RICH SHALES WITH COMMON CARBONACEOUS SPECKS OR LAMINAE. TRACES OF PYRITE WERE PRESENT. THE K-10 AND HRZ ARE DISTINCTIVE MARKERS FOR CORRELATING THE DISTANCE TO THE TOP OF THE KUPARUK SANDSTONE (PRIMARY OBJECTIVE). ALTHOUGH CUTTINGS SAMPLES ARE SOMEWHAT DISTINCTIVE, A MORE EXACT METHOD FOR DETERMINING THE TOPS OF THE K-10 AND HRZ IS BY USING THE MWD GAMMA RAY. DRILL RATE AND GAS DATA THE DRILL RATES RANGED FROM 20 TO 80 FEET PER HOUR IN THIS HOLE SECTION. THE AVERAGE DRILL RATE WAS 40 FEET PER HOUR. DITCH GAS RANGED FROM 80 TO 220 UNITS, AND AVERAGED 150 UNITS. C1 THROUGH C4 WERE PRESENT THROUGHOUT THIS INTERVAL. AN INCREASE IN THE HEAVIER (C3+) GASSES CAN BE ATTRIBUTED TO THE HIGH ORGANIC CONTENT OF THESE SHALES AND ALSO TO THEIR OVERLYING PROXIMITY TO THE OIL-BEARING KUPARUK SANDSTONE. HIGH CUTTINGS/BLENDOR GAS WAS ALSO DETECTED (10 - 28 UNITS), SUBSTANTIATING THE HIGH ORGANIC CONTENT, YET LOW PERMEABILITY, OF THESE SHALES. OIL AND GAS SHOWS DULL GOLD SAMPLE FLUORESCENCE AND MILKY YELLOW SOLVENT CUT WERE OBSERVED THROUGHOUT THIS INTERVAL. ABUNDANT BLUE MINERAL FLUORESCENCE ASSOCIATED WITH THE VOLCANIC TUFFS WAS ALSO VERY DISTINCTIVE. A SHOW RATING OF POOR WAS GIVEN THE INTERVAL DUE TO THE POOR PERMEABLILITY AND RESERVOIR CHARACTER OF THE ROCK (I.E. SHALE, SEE APPENDIX FOR SHOW REPORT). -6- KALUBIK AND KUPARUK SECTION LITHOLOGY THE KALUBIK WAS DRILLED AT ABOUT 8645 FEET TVD (9615' MD) AND THE KUPARUK WAS FROM APPROXIMATELY 8680 TO 9650' TVD (9650'- 10390' MD). THE KALUBIK WAS FIRST ENCOUNTERED BEFORE USING OIL BASED MUD, WHICH MADE CUTTINGS ANALYSIS A BIT LESS DIFFICULT. IT CONSISTED OF A LIGHT TO MEDIUM GRAY BROWN SILTSTONE WITH RARE GLAUCONITE. TRACES OF TUFF AND PYRITE'WERE ALSO COMMON. THE 9 5/8" CASING WAS SET IN THE KALUBIK FORMATION, SO THAT CORING OF THE FORMATION CONTACT BETWEEN THE KALUBIK AND KUPARUK COULD BE ACHIEVED. THE KUPARUK SANDS (PRIMARY OBJECTIVE) WERE ENCOUNTERED APPROXIMATELY 5 FEET INTO THE FIRST CORE (8680' TVD, 9650' MD). CUTTINGS SAMPLES OF THE KUPARUK SANDSTONE DURING INITIAL STAGES OF CORING WERE POOR. HOWEVER, CLOSE INSPECTION SHOWED THE SANDSTONE TO BE VERY FINE TO FINE GRAINED, BECOMING MEDIUM TO COARSE GRAINED WITH DEPTH. THE SANDS WERE GENERALLY CLEAR TO'BROWN OIL STAINED, SUB-ROUNDED QUARTZ WITH SLIGHT TRACES OF GLAUCONITE. SORTING WAS MODERATE TO C~)OD. SAND GRAINS WERE UNCONSOLIDATED IN CUTTINGS SAMPLE, EXCEPT AT THE BASE OF THE KUPARUK WHERE CALCITE CEMENTATION WAS OBSERVED. DARK GRAY SHALE AND SILTSTONE WAS PRESENT IN VARYING AMOUNTS WITHIN THE KUPARUK, PRESUMABLY AS INTERBEDS IN THE SANDSTONE. VISIBLE POROSITY IN THE SANDSTONE WAS GENERALLY VERY GOOD (I.E. UNCONSOLIDATED). IN THE 9980' TO 10550' SAMPLES ABUNDANT RED IRON STAINING WAS OBSERVED WITH PROBABLE ASSOCIATED SIDERITE. DRILL AND GAS DATA MOST OF THE SECTION WAS CORED, WITH AN 8-1/2" CORING ASSEMBLY. NINE CORES WERE TAKEN FROM 8675 FEET TO 9215 FEET TVD (9646'- 10237' MD). CORING RATES RANGED FROM 5 TO 140 FEET PER HOUR, AVERAGING 30 FEET PER HOUR. CORE RATES WERE HIGHEST IN THE LOWER PORTION OF THE KUPARUK, AND AVERAG]~ NEARLY 60 FEET PER HOUR IN THESE ZONES (CORES 7 THROUGH 9). DRILLIN(] ABOVE AND BELOW THE CORED INTERVAL AVERAGED 30 FEET PER HOUR. GAS READINGS RANGED FROM 10 TO 130 UNITS, AND ALSO COINCIDED WITH AND DRILLING BREAKS. THE AVERAGE GAS READINGS DURING THE FASTEST CORING INTERVAL (CORES 7 THROUGH 9) WERE 95 UNITS. C1 THROUGH C4 WERE PRESENT THROUGHOUT MUCH OF THE INTERVAL. WITH C4 DROPPING TO ZERO IN AREAS OF LOWER TOTAL GAS READINGS. OIL AND GAS SHOWS LVT - ZOO (MINERAL OIL-BASED CORING MUD) WAS USED AFTER THE 9 $/8" CASING, MAKING SHOW EVALUATION MORE DIFFICULT. HOWEVER, IT WAS QUITE APPARENT THAT A SUBSTANTIAL AMOUNT OF OIL WAS PRESENT IN THE KUPARUK SANDSTONE BASED ON THE ABUNDANT OIL STAINING OF THE SAND GRAINS AND HIGH GAS AND DRILL RATES ENCOUNTERED. VISIBLE POROSITY, WHERE SANDS WERE NOT ENTIRELY UNCONSOLIDATED, WAS GOOD TO VERY GOOD. FLUORESCENCE AND SOLVENT CUTS OF THE SAMPLES AGAIN WAS LARGELY SKEWED BY THE MINERAL OIL BASED MUD. SAMPLE FLUORES- CENCE WAS GENERALLY 100%, WITH AN INSTANT BRIGHT MILKY GREEN- ISH YELLOW CUT FLUORESCENCE. VISIBLE CUTS RANGED FROM MEDIUM TO DARK BROWN. RESIDUAL CUTS RANGED FROM DARK AMBER TO DARK BROWN. THIS SHOW WAS GIVEN A GOOD TO VERY GOOD RATING (SEE APPENDIX FOR SHOW REPORT}. MILUVEACH SECTION LITHOLOGY THE TOP OF THE MILUVEACH WAS ENCOUNTERED AT APPROXIMATELY 9350' TVD (10390' MD). CUTTINGS SAMPLES CONTAINED PROGRESSIVELY HIGHER PERCENTAGES OF MEDIUM GRAY-BROWN AND BROWN SUB-FISSILE SHALE OR MUDSTONE. MINOR MEDIUM GRAY SILTSTONE WAS ALSO PRESENT. THE WELL PLAN CALLED FOR DRILLING 100 FEET OF THE MILUVEACH, IN ORDER THAT SUFFICIENT "RAT HOLE" WOULD BE PRESENT FOR ELECTRIC LOG AND PRODUCTION LINER RUNS. THE WELL WAS TD'D IN THE MILUVEACH AT 9452' TVD (10500' MD). DRILL AND GAS DATA THE DRILL RATES IN THIS SECTION WERE FAIRLY CONSISTENT. RATES RANGED FROM 10 TO 35 FEET PER HOUR, WITH AN AVERAGE OF 25 FEET PER HOUR. GAS READINGS IN THIS SECTION WERE LOW AVERAGING 5 UNITS. C1 THROUGH C3 WAS PRESENT THROUGHOUT MUCH OF THIS SECTION. OIL AND GAS SHOWS OIL SHOWS GRADUALLY DECREASED IN THIS HOLE SECTION. PRESUMABLY, ANY FREE OIL AND STAINING WERE A RESULT OF THE OVERLYING KUPARUK SANDS. -8- APPENDIX I. SHO~ REPORTS SHOW REPORT #1 OIL COMPANY: PRUDHOE BAY DRILLING WELL NAME: P1-20 LOCATION: NORTH SLOPE,AK. DATE:VARIOUS TIME: SHOW INTERVAL: ?330' TO 9260'(MD) 6800' TO 8340'TVD) BIT SIZE: 12.25" MUD WEIGHT: 9.? ppg WOB: 35 klb LOGGING COND: GOOD BIT TYPE: VARIOUS VISCOSITY: 42 RPM: 100 HOURS: FILTRATE: 6.1 PUMP PR: 3200 FEET: EST. PORE PRES: 9.6 PUMP SPM: 150 BEFORE DURING AFTER ROP XX 10- 500 30- 211 TOT GAS XX 10- 500 60- 1375 C1 XX 30K AVE. -------- 84K C2 XX 1000 AVE. 15K C3 XX 600 AvE. 7K C4 XX 300 AVE. 3K C5 CHL XX XX --~---- .... 1100 .... 800 LITHOLOGY BEGIN LOGGING @ 9520' SANDS/SANDSTONE, WITH ABNT FLOATING CONGLOM, SH/SLTST SANDSTONE, SILTSTONE OIL IN MUD: NONE - DK BROWN TARRY FLUOR: NONE-DULL GOLD SOLVENT CUT FLUOR: YELLOW - MLKY YELLOW INTENSITY: DULL-BRIGHT UNWASHED CUTT FLUOR: PALE-BRI YELLOW TYPE & SPEED: V SLOW STREAMING- INSTANTANEOUS WASHED CUTT FLUOR: PALE YELL NAT COLOR & RESIDUE: NONE-MED BROWN STAIN: NONE-BROWN VISUAL POROSITY: NONE-POOR SHALE/CLAYSTONE: LIGHT TO MEDIUM GRAY BROWN, VERY SOFT, SILTY AND CONGLOM., SLIGHTLY CALC, TRACE TO COMMON PYRITE, MICRO MICA, GCC TUFF, GCC - RR INOC. SILTSTONE: LIGHT - MEDIUM GRAY BROWN, COMMONLY SANDY, MINOR CONGLOMERATE. CONGLOMERATE/SAND: BROKEN PEBBLES PRESENT THROUGHOUT, GCC SANDSTONE INTBDS. COMMENTS: WEST SAK. GENERALLY LITTLE FLUORESCENCE AND AREAS OF VERY TARRY DARK BROWN OIL. BEST SHOWS FROM 7300'-8600' MEASURE DEPTH. RATING: FAIR ( 3 ) LOGGING GEOLOGIST: DOUG FORSTER GARY HAMBURG SHOW REPORT #2 OIL COMPANY: PRUDHOE BAY DRILLING WELL NAME: P1-20 LOCATION: NORTH SLOPE,AK DATE: 10/18/92 TIME: 09:36 SHOW INTERVAL: 9275' TO 9320'(MD) - 10:26 8344' TO 8380'TVD) BIT SIZE: 12.25" BIT TYPE: STC MFDSH 1-G HOURS: 2.8 FEET: 75 MUD WEIGHT: 10.2 ppg VISCOSITY: 45 FILTRATE: 5.8 EST. PORE PRES: 9.8 WOB: 60 klb LOGGING COND: GOOD RPM: 115 PUMP PR: 3650 PUMP SPM: 184 BEFORE DURING AFTER ROP 25- 35 30- 211 25- 30 TOT J. GAS 50- 90 60 - 1375:MAX. ! 60- J 7K 80 JAVE. C1 C2 6K 300 AVE. AVE. 84K 15K MAX. 550 AVE. C3 180 AVE. 7481 MAX. 250 AVE. OIL IN MUD: TRACE DARK BROWN FLUOR: TRACE YELLOW UNWASHED CUTT FLUOR: TRACE YELLOW WASHED CUTT FLUOR: BRASSY GOLD - BRIGHT YELLOW STAIN: BROWN - DARK BROWN C4 AVE. 2855 AVE. 130 AVE. C5 CHL 800 8OO .... 800 I__ LITHOLOGY WEST SAK SHALES AND SILTSTONE. SANDSTONE, ABNT SHALE,COMI SLTY SS, TRACE VOLC TUFF SHALE, ABUNDANT VOLCANIC TUFF,SLTY SANDSTONE INTBD SOLVENT CUT FLUOR: TRACE WEAK BLUE WHITE STREAMING INTENSITY: SLOW - WEAK TYPE & SPEED: SLOW STREAMING NAT COLOR & RESIDUE: NONE TO TRACE MEDIUM BROWN VISUAL POROSITY: FAIR SANDSTONE: I~IUM GRAY, BROWN OIL STAINED, W/ CHALKY TUFF, VERY SILTY IN PART, TUFF AND SHALE INTERBEDS, COM PYRITE, GCC TUFF, RR INOC. SHALE: MEDIUM GRAY BROWN, SUBFISSILE, CARBONACEOUS, MICRO MICA. VOLCANIC TUFF: LIGHT GRAY, WAXY - CHALKY, MICRO-CRYSTALLINE. COMMENTS: UNNAMED SANDSTONE (STUMP ISLAND?). POOR SAMPLE AND CUT FLUOR- ESCENCE. Cd)OD INCREASE IN GAS READINGS. TRACE OIL IN MUD. FAIR VISIBLE POROSITY BUT RATHER SILTY. POSSIBLE GAS RESEVOIR. RATING: FAIR - MOD. GD ( 4 ) LOGGING GEOLOGIST: GARY HAMBURG GOOD GAS SHOW, POOR OIL SHOW DOUG FORSTER SHOW REPORT #3 OIL COMPANY: PRUDHOE BAY DRILLING WELL NAME: P1-20 LOCATION: NORTH SLOPE,AK DATE:VARIOUS TIME: SHOW INTERVAL: 9400' TO 9650'(MD) 8460' TO 8680'TVD) BIT SIZE: 12.25" BIT TYPE: VARIOUS MUD WEIGHT: 10.0 ppg VISCOSITY: 42 WOB: 55 klb LOGGING COND: GOOD RPM: 100 HOURS: FILTRATE: 6.4 PUMP PR: 3500 FEET: EST. PORE PRES: 9.7 PUMP SPM: 160 BEFORE DURING AFTER ROP 30- 211 20- 80 10- 160 TOT GAS 60- 1375 75- 275 10- 125 C1 C2 84K 15K MAX. MAX. 20K 1000 AVE. 30K MAX. C3 7500 MAX. 6OO AVE.:AVE. 1000 250 MAX. MAX. OIL IN MUD: NONE - TRACE FLUOR: SPOTTY DULL GOLD UNWASHED CUTT FLUOR: MLKY YELLOW WASHED CUTT FLUOR: BRIGHT MLKY YELL STAIN: NONE C4 2855 MAX. 3OO AVE. 90 MAX. C5 CHL 8O0 8OO OIL MnUD LITHOLOGY SANDSTONE, SHALE INTDS, MNR VOLCANIC TUFF SHALE, ABUNDANT VOLCANIC TUFF,SLTY SANDSTONE INTBD GLAUCONITIC SANDSTONE. (CORED INTERVAL) SOLVENT CUT FLUOR: MLKY YELLOW INTENSITY: BRIGHT TYPE & SPEED: INSTANTANEOUS NAT COLOR & RESIDUE: PALE STRAW TO MEDIUM BROWN VISUAL POROSITY: NONE SHALE/CLAYSTONE: MEDIUM TO DARK GRAY, VERY FISSILE IN PART, SILTY AND SANDY INTERBEDS, ABUNDANT VOLCANIC TUFF INTERBEDS, OCC INOC, BECOMING LIGHT TO MEDIUM GRAY BROWN SHALE AT 9615' OCC SIDERITE, RARE PYRITIC SHALE. COMMENTS: K-10, K-5/HRZ, KALUBIK. GOOD CUT FLUORESCENCE IS DUE TO THE VERY ORGANIC RICH (CARBONACEOUS) NATURE OF THESE SHALES. VERY POOR VISIBLE POROSITY (SHALES). GOOD SOURCE ROCK. RATING: POOR - FAIR ( 2 ) LOGGING GEOLOGIST: DOUG FORSTER RALPH WINKELMAN SHOW REPORT #4 OIL COMPANY: PRUDHOE BAY DRILLING WELL NAME- P1-20 LOCATION: NORTH SLOPE,AK DATE:VARIOUS TIME: SHOW INTERVAL: 9650' TO 10390'(MD) 8680' TO 9350'TVD) BIT SIZE: 8.§" MUD WEIGHT: 10.2 ppg WOB: 6 klb LOGGING COND: FAIR BIT TYPE: EAST-TELE VISCOSITY: 65 CORE BIT HOURS:VARIOUS FILTRATE: RPM: 50-80 PUMP PR: 1200 FEET: EST. PORE PRES: 9.8 PUMP SPM: 71 BEFORE DURING AFTER TOT ROP GAS 20- 75- 80 275 10- 10- 160 125 10- 35 5 Cl 20K AVE. 30K MAX. -------- 200 OIL IN MUD: OIL-BASED MUD FLUOR: DULL YELLOW C2 1000 AVE. 1000 MAX. :MAX. 20 10 C3 C4 600 300 AVE. AVE. 250 90 MAX. TR C5 CHL 800 OIL MUD OIL MUD LITHOLOGY SHALE, SILTSTONE, COMMON VOLCANIC GLAUCONITIC SANDSTONE, COMMON SHALE INTBDS SHALE, MUDSTONE, COMMONLY SILTY SOLVENT CUT FLUOR: GN YELLOW - MLKY YELLOW INTENSITY: BRIGHT UNWASHED CUTT FLUOR: DULL YELLOW TYPE & SPEED: INSTANTANEOUS WASHED CUTT FLUOR: DULL YELLOW (100%) NAT COLOR & RESIDUE: MED - DK BROWN STAIN: MEDIUi~ - DARK BROWN VISUAL POROSITY: GOOD SAND/SANDSTONE: CLEAR - BROWN OIL-STAINED SAND,LOOSELY CONSOLIDATED - FIRM, VERY FINE TO MEDIUM GRAINED QUARTZ SAND, PREDOMINATELY SUB- ROUNDED TO SUB-ANGULAR, TRACE GLAUCONITE, TRACE SIDERITE CEMENT IN CORES, OCCASIONAL SHALE INTERBEDS, GOOD VIS.POROSITY -PRIMARY OBJECTIVE- COMMENTS: KUPARUK SANDS. SHOW EVALUATION IS MASKED BY THE OIL-BASED MUD BEING USED AND CORING. HOWEVER, DRILL RATE GAS INCREASES, AND GOOD VISIBLE POROSITY, ARE INDICATIVE OF A GOOD RESEVOIR ZONE. RATING: GOOD - V. GOOD ( 5 ) LOGGING GEOLOGIST: DOUG FORSTER RALPH WINKELMAN APPENDIX II. BIT RECORD BIT DATA RECORD RUN : BZt : NER : TYPE ', SIZE : XADC I JET : START : DRILLED : AVG : ~OB ** RP~I ~ PUHP : SPPI/GPH : BIT # f t f ~ *, ~ CODE ~ SIZE ~ DEPTH I FT. : HRS ~ ROP :X1000:(ROT)', PRESS~ ',COND 3 ~ 3 ~REED ~EHPSIHSCI~ J 12.25"~ :2X11,12,15~ 6467' ~ 135' : 2.1 ~ 64.3 I 48 ~ 90 : 3200 ', 185/800 ..... 4. .....4. ........4 + 4. ...... 4. 4 i- .......4. ..... 4- .......4. ..... 4. ..... 4. ......4, .........4. ..... 4 ~ 4 ~SI~ITH ',FXC ~ 12.25'*~ :3116,12 ~ 6602' : 2294' :45.7 ~ 50.2 ~ 48 ~ 85 I 3600 : 185/800 : ..... + ..... + 4. .......... + + ...... + + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... 5 J 5 :SI'IITH IN:PDC S-85 : 12.25": 12Xi4,4X13: 8896' : 304' : 5.3 : 57,4 : 15 : 90 : 3600 : 185/800 ..... + ..... + + 4. + ...... + + ~ ....... + ..... + ....... + ..... + ..... + ...... + ......... 6 J 6 ~SI'IITH : I'IFDSH l-G: 12.25": :3X16,12 : 9200' : 437' :13.8 : 31.7 : 55 : 110 : 3730 : 185/800 ..... + ..... + + .......... + ........ + ...... 4. .........+ 4- .......+ .....+ ....... 4. ..... + .....+ ...... + ......... + ..... 7 ~ 7 ~S~'IITH ~ F-15 : 8.5" : ', OPEN ', 9637' ~ 1' ~ .1 ~ N/A ~ DRILLED CEPIElqT FLOAT/SHOE, 1 FT ..... + ..... + ........ 4. t- ........+ ...... + ......... + + ....... + .....+ ....... + .....+ .....+ ......+ + ..... 8 : 8 :EAS-TELE: SC-712 : 8.5" : :0.95 TEA : 9646' : 59' : 4.2 ', 14.0 : 12 : 90 : I200 : 70/30S ',COREl ..... + ..... 4 4. .......... + ........ + ...... + ......... + 4.,. ...... + .....+ ....... 4. ..... + .....+ ......+ + ..... 9 : 8.iIEAS-TELEI SC-712 : 8.5" I 10.95 TEA : 9705' : 59' : 6.2 : 9.5 ', 15 : 90 : 1200 : 75/324 ICORE2 ..... + ..... + ........ + .......... + ........ + ......+ i 4. .......+ .....+ ....... + .....+ .....4- ...... + .+ ..... 10 : 9 IEAS-TELEI SC-712 : 8.5" : 10.95 TEA : 9764' : 59' I 3.7 I 15.9 : 15 : 90 ', 1100 I 75/324 :CORE3 ..... + ..... + ........ 4 + ........ + ...... + ......... + ......... + ....... + .....+ ....... + .....+ .....+ ...... + ......... + ..... 112 I 9.1:EAS-TELE~ SC-712 : 8.5" : 10.95 TEA : 9823' : 59' : 3.7 : 15.9 ', 15 : 90 : 1200 : 75/324 :CORE4', ..... 4. .....+ ........ 4. .......... + + ...... + ......... + ......... + ....... + .....+ ....... + .....+ .....+ ...... + ......... 13 I 9.2:EAS-TELE: SC-712 : 8.5" : 10.95 TEA : 9882' : 59' : 4.8 : 12.3 : 14 : 90 ', 1200 : 75/324 ',CORES: ..... + ..... + ........ , + + ...... + , 4. .......+ .....+ ....... + ..... + ..... + ...... + ......... 4. ..... 14 I 10 :EAS-TELE: SC-712 : 8.5" : :0.95 TEA : 9941' : 59' : 2.7 : 21.9 : 13 : 91 : 1230 : 75/324 :CORE6~ ..... + ..... + + .......... + + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... 15 : 11 :E~A.S-TELg: RC-412 ~ 8.5" : :0.50 TEA : 10000' : 89' : 2.0 : 44.5 : 7 : 80 : 1400 : 75/324 :CORET: ..... + ..... + + .......... + + ...... + ......... + ......... 4. .......+ .....4. .......+ .....+ .....+ ...... + ......... + ..... 16 : ll.I',EAS-TELE: RC-412 I 8.5" : :0.50 TE& I 10089' : 89' : Z.0 : 44,5 : 8 : 90 : 1350 ', 75/324 ',CORE8 ..... + ..... + + .......... + 4. ......+ ......... 4. .........+ ....... + .....+ ....... + .....+ .....+ ...... 4. .........+ ..... 17 : ll.2:F...AS-TELE: RC-412 : 8.5" : ',0.50 TEA I 10178' { 59' : 1,0 : 62,0 : i0 : 91 : 1330 : 75/324 :CORE9 ~ .....+ .....+ + : 18 : 7.1:SI~IXTH I E-15 ~ .....+ .....+ + ~ .....+ .....+ ........ + I 8.5" : :OPEN I 10237' : 263' : 16.0: 16.4 : 30 : 85 : 2400 : 150/650 :TD I' 4. ...... 4 + I- .......+ .....+ ....... + .....+ .....+ ...... + ......... + ..... 4. 4. ...... + ......... + ......... + ....... + .....4. .......+ .....+ .....+ ......+ ......... + ..... I ~ ......4. .........4. + ....... + .....+ ....... + .....+ .....+ ......+ + ..... ARCO Alaska, Inc. Lisburne/Point Mclntyre Engineering Date: June 4, 1993 Subject: Transmittal #325 From: ARCO Alaska Inc. To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre Equity Well Core Analysis Reports are enclosed. These are being sent in response to Larry Grant's request of 4/19/93. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Report _ Well _, ;t'~P2-50 Please Core Analysis Report Core Analysis Report Core Analysis Report Core Analysis Report Core Analysis Report Core Analysis Report Core Analysis Report Core Analysis Report Core Analysis Report si~ and Transmittal #325 Run Date Company 1/8/93 Core Labs 2/10/93 Core Labs 2/24/93 Core Labs 1/12/93 Core Labs 2/11/93 Core Labs 7/7/92 Core Labs 7/22/92 Core Labs 8/12/92 Core Labs 11/24/92 Core Labs return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. 100 60 Anchorage, Alaska 9951 PLEASE SIGN ONE COPY AND RETURN June 4,1993 Page 2 Reports Well Final Well Report Final Well Report Final Well Report Final Well Report Final Well Report Final Well Report Final Well Report Final Well Report Run Date 9/8-10/10/92 10/19-11/5/92 9/11-10/4/92 12/2-27/92 10/13-28/92 7/3-26/92 5/22-6/18/92 11/8-12/8/92 Company Exlog Exlog Exlog Ex, log Exlog Exlog Exlog Exlog Please Formerly PM#3 Transmittal #326 and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 PLEASE SIGN ONE COPY AND RETURN Date: Subject: From: To: ARCO Alaska, Inc. .. Lisburne/Point McIntyre Engineering June 4, 1993 Transmittal #326 ARCO Alaska Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Logs Well (one blueline, one sepia) ~'[~(P1-14 Perforating Record & Jewelry Log (GR/CCL) \P1-14 CDR Enhancement (LWD/Depth Corrected) ~~ P1-02* P1-G1 IP1-G1 kP1-G1 Production Profile Gamma Ray Survey Integrated Forma__tion Log-MD Integrated Formation Log-TVD Engineering Parameters Pressure Data Log ~ P2-48 ka / P2-48 0('t~\~ /P2_48 xP2-48 Integrated Formation Log-MD Integrated Formation Log-TVD Engineering Parameters Log Pressure Data Log Run # Run Date Company 5/1293 Schlumberger 3/5/93 Schlumberger 1/26/93 Camco 11/8-17/92 Exlog 11/8-17/92 Exlog 11/8-17/92 Exlog 11/8-17/92 Exlog 12/2-27/92 Exlog 12/2-27/92 Exlog 12/2-27/92 Exlog 12/2-27/92 Exlog Tapes w/Verification Listing Well ~ ~a'7~ Run # PI-11 :G ~dit- Bit Runs 1-7 in LDWG Format cmpst Pl-14 ~ Edit-CDN/CDR in LDWG Format & QRO 1 Run Date 10/3/92 03/05/93, Company Schlumberger Schlumberger PLEASE SIGN ONE COPY AND RETURN ARCO Alaska, Inc. Lisburne/Point McIntyre Engineering Date: Subject: From' To' April 13, 1993 Transmittal #299, ARCO Alaska Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 RECEIVED APR 7 zl 1995 Alaska Oil & Gas Cons. Commis61on Anchorage The following Point McIntyre Equity Well data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well 1 blue line, 1 sepia °2-55-' Integrated Formation Log-MD q'&'%/~P2-55~ Integrated Formation Log -TVD I P2-55~,/Engineering Parameters / ~-P2-55" Pressure Data Log r'P1-20 v" Integrated Formation Log -MD P1-20 ~/'Integrated Formation Log-TVD o :,P1-20'/Engineering Parameters P1-20-' Pressure Data Log° P1-20 .-" PFC Log c/ P1-20 ~/'Gamma Ray Log *,P1-20 ~/Completion Record ('P2-3~ Integrated Formation Log-MD a°"J~ )P2-30~'-- Integrated Formation Log-TVD · I P2-30~Engineering Parameters ~,P2-30 ~ Pressure Data Log Run # Run Date Company - 9/8-10/9/92 - 9/8-10/9/92 - 9/8-10/9/92 - 9/8-10/9/92 - 9/12-10/2/92 - 9/12-10/2/92 - 9/12-10/2/92 - 9/12-10/2/92 I 1/3/93 1 1/4/93 1 1/22/93 - 10/20-11/5/92 - 10/20-11/5/92 - 10/20-11/5/92 - 10/20-11/5/92 <~t6z ~ .~P1-02 ! P1-11~,-'Integrated Formation Log-MD - .9/12-10/2/92 PI-11 ,//'Integrated Formation Log -TVD , .7/~x~'/12-10/2/92 PI-Ill-'Engineering Parameters ~O~__. 9/12-10/2/92 PI-ll V' Pressure Data Log ~ ~ ..k.-~°~/12-10/2/92 PI-ll ~' Gamma Ray (Position Packer Assy)~, .x ,61 (~; 1 · 12/31/93 Pl-llx.' ~ Gamma Ray (Perforating P. cccrd~~'' 1 12/30/93 ~P1-11 "' Perforating Record 3 3/8" 4 spf I 1/26/93 · --' Perforating Record I 1/28/93 Exlog Exlog Exlog Exlog Exlog Exlog Exlog Exlog Atlas Atlas Schlumberger Exlog Exlog Exlog ,-' Exlog Exlog Exlog Exlog Exlog Atlas Atlas Atlas Haliburton Please sign 1 copy and return TO: STATE of ALASKA OIL/GAS CON. COMM. 3001 PORCUPINE ANCHORAGE, ALASKA DATE: 5 FEB., 1993 AIRBILL: AL 646224 AFT#: 03-02-05- CHARGE CODE: P16146 OPERATOR: ARCO SAMPLE TYPE: DRIES WELLS:P2-48/P1-20/P2-30/P1 -Gl NUMBER OF BOXES: 46 SAMPLES SENT: CORE CHIPS P2-48 P1 -20° CORE#1 CORE#2 CORE #3 CORE #4 CORE #5 CORE #2 CORE #3 CORE #4 CORE #5 CORE #6 CORE #7 CORE #8 CORE #9 BOX BOX BOX BOX BOX BOX BOX BOX ~ V BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX BOX #1 ~ #2 #1 #2 #3 ~'' #1-' #2 ~/ #I .,' #2 u/ #1 #2 #1 #2 #1 #2 #1 #2 #1 #2 #1 #2 #3 #1 #2 #3 #1 #2 15511'-15543' 15545'-15578' 15579'-15604' 15604'-15634' 15635'-15661' 15662'-15694' 15693'-15726' 15727'-15782' 15782'-15834' 15835'-15841' 9705'-9747' 9748'-9764' 9764'-9799' 9800'-9822' 9823'-9856' 9857'-9882' 9882'-9911' 9912'-9940' 9941'-9974' 9975'-9999' 10000'-10033 10034'-10063 10064'-10090 10089'-10120 10121'-10150 10151'-10179 10178'-10213' 10214'-10238' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMP LETION REPORT AND LOG OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE i"3 ~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-94 13. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-22288 4. Location of well at surface 9. Unit or Lease Name 1384' NSL, 908' WEL, SEC. 18, T12N, R14E, UM ::~ ~ ;;-:: :: ............. ~ i,tlLOCATK:~tS Point Mclntyre Al Top Producing Interval ~' ~,~.:.?;: ~ I[ YE~F.J__ED . 10. Well Number ~ ~ ~ ~"--' ,' P1-20 792'SNL, 1492' WEL, SEC. 16, T12N, R14E, UM; ~'=~-.,¢, 'Sur : ~'~:~ ~ ~.H,~t 11. Field and Pool UM ..... /¢.~. ...., t . ~ PointMcintyro At Total Depth 440'SNL, 1475' WEL, SEC. 16, T12N, R14E, ~' 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. KBE = 50.8' I ADL 28297 12. Date Spudded10/8/92 13. Date T.D. Reached10/28/92 14' Date C°mp" Susp' °r Aband' i15' Water Depth' if °lfsh°re 116' NO' Of COmpletiOns1111/92 NIA feet MSL Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey ~20. Depth where SSSV set ~1. Thickness of Permafrost 10500' MD/9453' 7'VD 10408' MD/9369' TVD YES [] N:) []! N/A feet MD ! Approx. 1750' ~'2. Type~ Electric or Other Logs Run Run # 1GR/CN/ZDL/DIFL Run # 2 MAC/GR 123. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 73' 30" 11 yds Arcticset 13-3/8" 88# L-80 40' 34 74' 18" 3837 cuft PF "E"/449 cuft C/ass "G 9-5/8" 47# L-80/NSCCi 41' 9637' 12-1/4' 1144 cuft C/ass 7' 26# 13CR80 41' 10500' 8-1/2" 211 cuft C/ass 'G 24. Pedorations open to Production (MD+IVD of Top and Bottom and 25. llJB~G R[CORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET (MD) Not Perforated None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etC.) Not yet on production I N/A Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE S[7_E IGAS-OIL RATI© TEST PERIOD I Flow Tubing Casing Pressure 'CALCULATED OIL--BBL GAS-MCF IWATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description o! lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. P/ease see attached core description. :, : .. ;;,.., il : ......... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. : 30. GEOLOGIC MARKERs FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Colville Group 6990' 6528' HRZ 9491' 8536' Kalubik 9603' 8637' Kuparuk 9651' 8680' Miluveach 10389' 9351' . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~/( ' ~ TitleDrillinoEnoineerSupervisor 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 spaces 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 producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. i' ? "i' r~ ~ ~ ~ ~.. ~ ~, Item 28: If no cores taken, indicate "none". Form 10-407 Core # 1 Core #2 Core #3 Core #4 Pt. McIntyre P1-20 Core Description 9646'-9705' Cut 59', recovered 59' Lithology: 9646'-9652' Shale, gray, fissile to subfissile, with thin (less than 1" thick) beds of coarse, tight, argillaceous, glauconite sandstone. 9652'-9654' Shale, brownish gray, fissile, sandy, pebbley, glauconitic, and tight. 9654'-9705' Sandstone, argillaceous, silty and pebbley, poorly sorted, glauconitic, burrowed, sideritic, tight. 9705'-9764' Cut 59', recovered 59' Lithology: 9705'-9740.4' Sandstone, argillaceous, silty, and sparsely pebbley, moderately to poorly sorted, glauconitic, sideritic, tight. 9740.4'-97.46.8' Sandstone, very fine to fine grained, quartzose, slightly argillaceous, burrowed, oil stained, tight to fair permeability. .. 9746.8'-9749.5' Sandstone, medium grained, poorly to moderately sorted, glauconitic, argillaceous, sideritic, tight to low permeability. 9749.5'-9764' Mudstone, interbedded sandy/sideritic and sandy/argillaceous, glauconitic, tight to low permeability, oil stained. 9764'-9823' Cut 59', recovered 59' Lithology: 9764'-9800.7' Sandstone, medium-coarse grained, locally pebbley, increasingly argillaceous near the top of the interval, glauconitic, moderately to poorly sorted, cemented by -siderite, tight, except scattered fair permeability across 9785- 9800', oil stained. 9800.7'-9812' Sandstone, fine to medium grained, moderately sorted, glauconitic, siderite cemented, burrowed, tight to good permeability, oil stained. 9823'-9882' Cut 59', recovered 59 Lithology 9823'-9841.2' Sandstone, fine to very coarse grained, moderately sorted, glauconitic, tight to fair permeability, sideritic, burrowed, lightly oil stained. 9841.2'-9866.3' Sandstone, fine to very coarse grained, moderately to well sorted, glauconitic, tight to excellent permeability, sideritic in lower part, oil stained, burrowed. 9866.3'-9882' Sandstone, fine to medium grained, well sorted, glauconitic, fair to excellent permeability, oil stained, scattered siderite cement, burrowed. ."'' .~i.~' i~ii '"~ :~'i' P1-20 Completion Rpt 1/25/93 Page 2 Core 5 9882'-9941' Cut 59', recovered 58.5' Lithology: 9882'-9932' Sandstone, fine to medium grained, well sorted, good to excellent permeability, oil stained, with scattered, patchy siderite cement, burrowed. 9932'-9940.5' Sandstone, fine to very coarse grained, poorly to well sorted, tight to good permeability, oil stained, sideritic. Core #6 9941'-10,000' Cut 59', recovered 58.4' Lithology 9941'-9949.5' Sandstone, fine grained, well-sorted, good to excellent permeability, oil stained. 9949.5'-9975.3' Sandstone, fine to coarse grained, moderately to well sorted, glauconitic, tight to good permeability, oil stained, siderite cemented, burrowed. 9975.3'-9999.4' Sandstone, medium grained to granular, poorly to well..sorted, glauconitic, tight, very sideritic, burrowed. Core #7 10,000'-10,091' Cut 89', recovered 91' Lithology 10,000'-10,008' Sandstone, fine to coarse grained, poorly to moderately sorted, glauconitic, tight, very sideritic, burrowed, 10,008'-10,019' Sandstone, fine-medium grained, well sorted, excellent permeability, oil stained. 10019'- 10081.3' Sandstone, fine grained to granular, poorly to well sorted, glauconitic, mostly tight, very sideritic, burrowed. 10081.3'-10091' Sandstone, fine to coarse grained, moderately to well sorted, glauconitic, fair to good permeability, oil stained, sideritic. Core #8 Core #9 10089'-10179' Cut 89', recovered 90' Lithology: 10,089'-10,137' Sandstone, very fine to coarse grained, poorly to well sorted, glauconitic, tight to good permeability, oil stained (oil/water contact' at approximately' 10, 137'), burrowed. 10,137'-10,151' Sandstone, very fine to coarse grained, moderately sorted, glauconitic, poor to good permeability, lightly oil stained, sideritic. 10,151'-10,179' Sandstone fine grained, well sorted, slightly glauconitic, poor to fair permeability, lightly oil stained, - sideritic, burrowed. 10178'-10238.4' - ~ Cut 59', recovered 60.4' P1-20 Completion Rpt 1/25/93 Page 3 Lithology: 10,178'- 10,224.1' Sandstone, very fine to fine grained, well sorted, slightly glauconitic and argillaceous, poor to fair permeability, lightly oil stained, siderit;ic, burrowed. 10,224'-10238.4' Sandstone, very fine to fine grained, well sorted, good to excellent permeability, lightly oil stained. BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: P1-20 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 1'0/07/92 11:00 SPUD: 10/08/92 09:00 RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 10/08/92 (1) TD: 110'( 0) 10/09/92 (2) TD: 1143' (1033) 10/10/92 (3) TD: 3500' (2357) 10/11/92 ( 4) TD: 3500' ( 0) 10/12/92 ( 5) TD: 4300' ( 800) 10/13/92 (6) TD: 6000' (1700) 10/14/92 ( 7) TD: 6650' ( 650) 10/15/92 (8) TD: 7883'(1233) RIG UP. MW: 8.5 VIS: 0 MOVE RIG F/ Pi-ll TO P1-20. RIG ACCEPTED @ 23:00 HRS, 10/7/92. N/U DIVERTER. DRLG. MW: 8.8 VIS:120 TEST DIVERTER. M/U BHA %1. SPUD WELL @ 09:00 HRS, 10/8/92. DRLG F/ 48'-244' POOH. CHANGE BHA. DRLG F/ 244'-512'. CIRC. SURVEY. DRLG F/ 512'-960'. CIRC. SURVEY. DRLG F/ 960'-1143'. CIRC. MW: 9.4 VIS: 78 DRLG F/ 1143'-1239' SHORT TRIP. REAM TO 1239'. DRLG F/ 1239'-1514' CIRC. DRLG F/ 1514'-1972'. CIRC. DRLG F/ 1972'-2433' CIRC. SHORT TRIP TO 1146'. DRLG F/ 2433'-2526' CIRC. DRLG F/ 2526'-2985'. CIRC. DRLG F/ 2985'-3500'. CBU. N/U BOPE. MW: 9.4 VIS: 42 CIRC. 13 STDS SHORT TRIP. CIRC. POOH. L/D BHA. RIH W/ 13-3/8" CSG. CIRC. PUMP 100 BBLS WATER, 1500 SX (580 BBLS) 'E' PERM CMT @ 12.2 PPG, 400 SX (80 BBLS) 'G' CMT @ 15.8 PPG. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. N/D DIVERTER. TOP JOB W/ 250 SX CSII @ 15 PPG. N/U BOPE. DRLG. MW: 9.1 VIS: 40 N/U BOPE. TEST BOPE. RIH W/ BHA #2. CIRC. TEST CSG. DRLG FC, CMT. TEST CSG. DRLG CMT, FS, TO 3510' CBU. LOT (12 PPG EMW). DRLG F/ 3510'-4300' DRLG. MW: 9.4 VIS: 38 DRLG F/ 4300'-5350'. SHORT TRIP. REAM THRU TIGHT SPOTS. DRLG F/ 5350'-6000' DRLG. MW: 9.5 VIS: 39 DRLG F/ 6000'-6470'. CBU. POOH. CHANGE BIT. RIH. DRLG F/ 6470'-6602'. POOH. 'CHANGE MTR. RIH. DRLG F/ 6602'-6650' DRLG. DRLG F/ 6650'-7883'. MW: 9.7 VIS: 38 WELL : P1-20 OPERATION: RIG : POOL 7 PAGE: 2 10/16/92 (9) TD: 8690'( 807) 10/17/92 (10) TD: 8895' ( 205) 10/18/92 (11) TD: 9200'( 305) 10/19/92 (12) TD: 9637' ( 437) 10/20/92 (13) TD: 9637'( 0) 10/21/92 (14) TD: 9637' ( 0) 10/22/92 (15) TD: 9656'( 19) 10/23/92 (16) TD: 9764' ( 108) 10/24/92 (17) TD: 9865' ( 101) 10/25/92 (18) TD: 9941'( 76) DRLG. MW: 9.8 VIS: 37 DRLG F/ 7883'-7980' CBU. SHORT TRIP 15 STDS. DRLG F/ 7980'-8690'. RIH W/ LOGS. MW:10.0 VIS: 41 DRLG F/ 8690'-8895' CIRC. POOH. P/U ANADRIL CDR TOOL. RIH TO 7138'. LOG TO BTM. RIH W/ LOGS. MW:10.1 VIS: 46 RIH W/ LOGS. DRLG F/ 8895'-9200' CBU. POOH. CHANGE BHA. RIH TO 9120' LOG TO BTM. POOH. MW:10.2 VIS: 41 RIH W/ LOGS. DRLG F/ 9200'-9520'. RELOG F/ 9490'-9520'. DRLG F/ 9520'-9637'. CBU. SHORT TRIP TO 9176'. CBU. POOH. CLEANING ANNULUS. MW:10.1 VIS: 38 POOH. TEST BOPE. R/U WOTCO. RIH W/ 9-5/8" CSG. CIRC @ SHOE. RIH W/ CSG. R/U CMT HD. CIRC. PUMP 20 BBLS ARCO PREFLUSH, 50 BBLS ARCO SPACER, 140 SX 'G' CMT W/ .5% CFR-3, 3% ECONOLITE, .4% HALAD 344 @ 11.1 PPG & 600 SX 'G' CMT W/ .2% CFR-3, .2% HALAD 344,.'.25% HR-5 @ 15.8 PPG. BUMP PLUG W/ 2000 PSI. N/D BOPE. SET SLIPS. CIRC. MW:10.1 VIS: 90 INSTALL SPOOL. N/U BOPE. TEST BOPE. L/D BHA. M/U BHA. RIH. CIRC @ 9555'. TEST CSG. DRLG FC, CMT, FS, 1' NEW HOLE. CBU. LOT (12.5 PPG EMW). CIRC. CORING. MW:10.2 VIS: 90 CIRC. DISP WELL W/ 10.2 PPG CORE FLUID. POOH. L/D BHA. RIH W/ CB #1. CBU. CORE F/ 9646'-9656'. POOH. MW:10.3 VIS: 88 CORE F/ 9656'-9705'. CBU. POOH. L/D CORE %1. RIH W/ CB #2. CBU. CORE F/ 9705'-9764' CBU. POOH. CORING. MW:10.2 VIS: 85 POOH. L/D CORE #2. RIH W/ CB. CBU. CORE F/ 9764'-9823' CBU. POOH. L/D CORE #3. RIH W/ CB. CBU. CORE F/ 9823'-9865'. RIH. MW:10.2 VIS: 78 CORE F/ 9865'-9882' CBU. POOH. L/D CORE #4' RIH W/ CB. CBU. CORE F/ 9882'~9941' .CBU. POOH. L/D CORE #5. RIH w/ CB. WELL : P1-20 OPERATION: RIG : POOL 7 PAGE: 3 10/26/92 (19) TD:10089' ( 148) 10/27/92 (20) TD: 10237' ( 148) 10/28/92 (21) TD:10270' ( 33) 10/29/92 (22) TD:10500' ( 230) 10/30/92 (23) TD:10500' ( 10/31/92 (24) TD:10500 PB: 0 o) 11/01/92 (25) TD: 10500 PB: 10408 11/02/92 (26) TD:10500 PB:10408 POOH. MW:10.2 VIS: 82 RIH. CBU. RIH. CORE F/ 9941'-10000' CBU. POOH. L/D CORE #6. RIH W/ CB. CBU. CORE F/ 10000'-10089'. CBU. POOH. L/D CB. MW:10.2 VIS: 85 L/D CORE #7. RIH W/ CB. CBU. CORE F/ 10089'-10178' CBU. POOH. L/D CORE #8. RIH W/ CB. CBU. CORE F/ 10178'-10237'. CBU. L/D CORE #8. L/D CORE EQUIP. DRLG. MW:10.2 VIS: 76 L/D CB. TEST BOPE. RIH W/ DRLG BHA. MAD RUN F/ 9637'-10237'. DRLG F/ 10237'-10270' R/U ATLAS. MW:10.2 VIS: 66 DRLG F/ 10270'-10500'. TD WELL @ 20:30 HRS, 10/28/92. CBU. SHORT TRIP TO 9630'. CBU. POOH. R/U ATLAS. RIH W/ 7" LNR. MW:10.3 VIS: 90 LOG RUN: GR/CN/ZDL/DIFL. LOG RUN: MAC/GR. R/D ATLAS. RIH W/ BHA. CBU. POOH. L/D BHA. RIH W/ 7" LNR. RIH. MW:10.4 OBM RIH W/ 7- LNR ON DP. CIRC @ SHOE. RIH. CIRC. CMT LNR. DISP W/ MUD. SET HGR & PKR W/ 4000 PSI. RELEASE F/ HGR. REV CIRC. POOH. RIH W/ CSG SCRAPERS. N/U TREE. MW: 9.8 NaCl RIH. TAG LC @ 10408' CBU. TEST CSG, LNR TOP PKR. CIRC. DISP WELL W/ 9.8 PPG NACL. POOH. DISP TOP 600' W/ DIESEL. POOH. L/D BHA. N/U TREE. RIG RELEASED. MW: 9.8 NaC1 N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 10:00 HRS, 11/1/92. SIGNATURE: (drilling superintendent) DATE: COMF'A~¥ A~£O ALASKA INC, WELL NAME P1-20 L[~Z:A?iON 1 LOCATION 2 ALASEA MA~N~iC DECLINATIO~ ~3,16 DATE: ll-~T-?2 WELL ~dMBEE WE~ HEAD L£~;ATI~4: LAI(N~-o~ 0.~ AZIM:JTH FR~ ROTAPY ?ABLE TO I'ARgE7 IS TIE IN POINT(TIP) MEASURED DE?TH 3428,00 ~:Ui VERT DE~TH 3427.59 ~" ? I' IN~.uIN~'~IOH 1,75 AZIMUTH 16.00 LAT!TUD:(N/-S) 16.50 DEPAFSUF',E(E/-W) 31.08 DEF'(E/-W) [~7o50 PAF_:E h~. 21 ~EF%H D£F'TH it ft ft 342~.00 0.'-:) 3427 3604,43 176,4 3603.82 3771,09 186.7 ~ ~':' 4164,64 167,6 4157,67 4344.99 4532,9 4718,0~ 4906,85 509i,1~ 518Z.01 546i,99 5M9.35 58~,27 6206,02 6299,66 65S1,%' &674.64 6765,49 6856,04 6947,46 7142,35 7513,44 6077.74 8265,63 8450,49 8541,9! 8635,54 90i8.34 9073,!I 9!21,07 92!6,26 160,1 167,3 4~O4,05 l~C_'.~. ~,35,36 184,3 4%'0,97 278,0 5295,64 187,4 5446,40 164,1 5744,30 166,7 ~a"'/ ~ 93,6 5969.6~ 67,8 6040,40 144,5 6157,26 142.7 "'~ ~ 90.~ 6347,67 92,6 6422.82 FT,4 64?4,83 194.9 6651,34 160.2 6795,.~. 190,5' 6945.21 199,4 7107,44 17o.o 7246,0& 191,4 167,9 7547.92 164,9 7693,71 91,4 7765,65 93,9 ~q""' 93+1 7913,55 197.0 8!41,62 54.~,_, F'i **e********** ANADRILL SL~:VEY CAL~%AT!ONS TARG~ ~T~I~ AZIMUTH LATITUDE SECTION INCLN, N/-S it d~ de~ it ¥,JP~ 1,75 16,00 1~,00 33,7~ 7,10 357,54 41,~3 59.83 9,10 349.63 67,88 97,39 14,02 34~.35 I)EF'AF-,~U~.:£ DISF'LACEMEt~ at AZIMUTH £/-W ft it de.a 3i,0E 25,19 62,04 ~,46 40,68 52,93 32,63 ~?,74 74.11 23,66 22.62 107.19 12.19 149,57 19,73 340,77 !55,13 218,24 23,5~ 343,67 220,81 2'78,[~ 27,74 E~3,07 2?7,75 391,88 31,85 342,54 387,59 490,31 ~,~ 344.02 100ft 0,00 1,06 1,92 1,22' 2,63 54!,4! 32,96 245,13 531,62 70i,59 36,46 346,44 696,97 812.82 36.36 348.71 795.5? 922,~ ~.,25 350,26 903,84 1032,12 36,~ 248,15 1011,23 8,72 155.36. 3,22 3,?? -12,34 221,15 356,~0 2,09 -~,33 ~P?,.M ~3,23 2,2? -62.2? 392 ~ ,~,., 35'),~7 2,1~ -89.S2 490,60 34'i',45 0,5S ~,4~ 1120,16 1143,25..' ~ r ~0 o~ 1196.7~ 36.31 348.76 1174,66 1250,8~ ~.,47 345,86 1225,80 1335,80 35,% 349.41 1309,23 1416,44 35,31 350,00 13%,61 -102,42. 541,59 34~.99 1,32 -142,79 701,~_'~ 348,26 0.94 -1~..72 812,88 248,16 0,72 -1..%,77 922,94 34E,.32 0,51 -207,24. 1032 ,~ -.r 248,42 0,72 1470.84 35,19 [~9.12 1442,17 152~,6~ 36,23 349.17 1495,23 1577,85 36,4~ 344.6I 1~7,06 1693.%' [%,6~ 347.13 1~.0.16 1601,85 36,66 3¢6,80 1765,25 -27?,26 1143,40 34~,.43 -240,00 1196,94 345.45 -25_0.12 1~5i.~5. ~8,47 -266,1~ 1336,¢I 348.51 -280.91 1418.7¢ ~8.5E 1916,62 37,0~: 346,73 1676.99 2036,56 q~ ''~ . ~,.,~ 348,1P: 1974.08 2140,66 ~5., 95 34g,74 Z.'~,.,,~.."r'"'z ~v 2255,24 27,21 34?,63 2207,65 2370,42 37,75 351,20 2322,3E 0,28 0,21 0,20 0,67 0.30 2463.64 38,13 ~3,65 2425.02 ~37,72 38,01 352,% 2491,01 2s~v.O° 37 ~ ~ 14 25_4~,02 2653,W0' 37,66 351,66 2710.59 36,1~ ~3,68 2660.77 -290.41 1471,12 ~8,61 0.58 -)[6,5E. 1525.14 348.63 1.13 -211,70 1576,15 348,61 1,72 -3:~.OE 1694,24 -362,42 1802,07 348.40 0,15 2830.22 37,79 ~,~r~ ..~v 2781.76 28~3.09 37,2E 3N,97 2£15,08 2771,72 ~6.75 5F,~..,,.ol Z840.=~ 2947,09 34.90 352,73 ~a'..'. ~- ?77,iS 31,¢~, . ~rr~_.; ,~:~"29'49 .... .~ -~£6,69 1916,~I 34S.30 -414.75 2036.76 34~.25 -435.61 2141,05 ~8,26 -457.26 2256.47 34.5.21 -476,30 2370.72 348,4i 0.11 0,44 0,20 0.31 0,56. -491,26 2484.09 2'48,59 0.84 -477,54 2540,27 ~8,70 0,4~ %05.79 25,97,73 348,77 1,29 -5i4,31 26~,67 ~8,83 -521,57 2711,41 348,91 1,39 %28,54 2831,53 -530,09 286~,56 349,34 -532.64 2~73.3(, -538.,64 2948,~4 -~3.92 2775,10 3~9,55 1.9¢' 5,37 1.10 2,3,?, PAGE NO, MEASL~ED IHTERVAL Vt~:TICAL DEPTH DEPTH 94:K),10 92.3 8456,38 9~:~4,27 1¢~.2 8547,99 %~6,70 82.4 6621,95 9706,~? 119.4 8730,~ 9796.37 92,3 8614,72 9900.14 100~J.64 10176,78 10274,47 10503,00 101,8 8907.40 187.5 o~ ~S 91,1 9160,29 9~.. 924~.,92 69.6 67.2 P1-20 ************* ANAJ~ILL ************** 9_~'.t~Y CALCL%ATIONS ***** RADIU:, OF CURVA'rL.IF~E METHOD******** TARGET STATIOH AZIML~H LATiTL?JEDEPARTURE DISPLACEMENT at SE~iOh tNCLN, N/-S E/-W ft deo deq ft ft ft ~43.66 29,25 355,% 27'76,1~,-547,52 3045.79 ~,~5 -$Sn ~' 3095,01 ~92,61 27,58. 357,04 ~ '~ ' . ~ _ 3i26,~ 24.82 269.98 S<382,02 -551,48 3130,96 _ .54' -550 3176,43 24.21 2,62 313! ,36 3179.54 3213.~;~ 24,28 2,78 3169,40 -548.58 3216,52 3~3,53 24.52 3.02 321!.36 -546,45 3257.54 ,~..5~ 24, 5.38 3289.51 -540,~' ~ % '~ 337~,14 3365,46 2~,z., 3,~ 332~,(~:, -~37 ~ 3404,53 25,03 3,2~ ~65,5~ -535,00 3410.~0 344i,31 24,30 4.26 34C~6,82 -532,48 344~,18 3468.?~ 23.97 6,2?. [,435.13 -52'?,87 3475,74. THE FINAL SL~;:~Y IS A F~:O:q~ED 93;:VEY ONLY, 3494,27 24.00 6.20 3462,?? -526,92 3502.16 AZIMUTH 349,64 349,75 349,B6 350.03 350,18 350,34 350.67 350,~2 350,% ~1,!2 ~i ,23 35_.,! deo/ lOOft 2,93 1,67 3,69 1,05 0,11 0.5~ 0.77 0,4C, 0,92 SUB- SURFACE DIRECTIONAL SURVEY ~-J UIDANCE ~ ONTINUOUS J-~ OOL Company 'Well Name Field/Location ARCO ALASKA, INC. P1-L~) (1384' FSL, 908' FEL,. . SEC 16, T12N, R14E) POINT HCINTYRE, NORTH SLOPE, ALASKA Job Reference No. 9266O LoCJcjed By: SCHWARTZ Date 02-NOV-92 Computed By: KRIJWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA SURVEY DATE: 2-NOV-g2 ENGINEER- SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 9 DEG 3! MIN WEST COMPUTATION DATE' 8-NOV-92 PaGE I ARCO ALASKA INCo P1-20 POINT M¢INTYRE NORTH SLOPE, ALASKA DATE Of SURVEY' 2-NOV-g2 KELLY BUSHING ELEVATION' 50.80 ET ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIk~JTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTL~E SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 oo 200 oo 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 699 99 799 99 899.99 -50.80 0 0 N 0 0 E 49.20 0 $ S 68 35 E 149.20 0 4 S 5 7 E 249.20 0 7 S 11 36 W 349.20 0 18 S 18 23 E 449.20 0 20 S 18 52 E 549,20 0 17 S 0 42 W 649.19 0 19 S 1 52 W 749.19 0 18 S 3 58 W 849.19 0 17 S 4 43 W 0 O0 -0 01 -0 I3 -0 30 -0 59 -1 21 -1 76 -2 28 -2 81 -3 30 0 O0 0 11 0 11 0 O0 0 O9 0 25 0 O0 0 O0 0 11 0 O0 000N 0 01$ 0 11 S 0 29 S 0 58S I 17 S I 71 S 2 24 S 2785 3 29 S 0 O0 E 0 04 E 0 15 E 0 10 E 0 13 E 0 36 E 0.42 E 0,41 E 0.38 E 0.34 E 0 O0 N 0 0 E O4 S 83 8 E 18 S 54 26 E 30 S 19 16 E 59 S 13 0 E 22 S 17 14 E 76 S 13 46 E 28 S 10 22 E 81 S 7 47 E 31 S 5 59 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 99 O0 1099 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1699 O0 1799 O0 1899 949.19 99 1049.19 99 1149.19 99 1249.19 99 1349 19 98 1449 18 98 1549 18 98 1649 18 98 1749 18 97 1849 17 0 14 S I 42 W 0 13 S 5 0 W 0 19 S 22 4 E 0 19 S 48 21E 0 18 S 56 23 E 0 19 S 64 17 E 0 18 S 69 42 E 0 36 S 73 50 E 0 35 S 82 59 E 0 47 N 83 25 E -3 75 -4 07 -4 50 -5 O4 -5 39 -5 75 -6 01 -6 42 -6 78 -6 96 0 O0 0 22 0 10 0 O0 0 O0 0 29 0 07 0 02 0 O0 0 19 3 755 4 07 S 4505 4 99 S 5 27 S S 56 S 5 74 S 6 03 S 6 23 S 6 21S 0.31 E 029 E 037 E 0 70 E 1 13 E 1 62 E 208 E 2 85 E 384 E 503 E 3 76 S 4 47 E O8 S 4 3 E 52 S 4 4O E O4 S 7 57 E 39 S 12 8 E 79 S 16 14 E 11 S 19 57 E 67 S 25 19 E 32 S 31 37 E O0 S 39 0 E 2000 O0 1999 96 1949 16 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2099 O0 2199 O0 2299 O0 2399 O0 2499 O0 2599 O0 2699 O0 2799 O0 2899 95 2049 94 2149 94 2249 93 2349 92 2449 90 2549 85 2649 79 2748 75 2848 15 14 14 13 12 10 05 99 95 0 50 N 77 42 E 0 41 N 84 5 E 0 39 S 83 2 E 0 37 S 80 27 E 0 45 S 89 19 E 0 57 N 81 8 E I 35 N 59 14 E I 57 N 37 47 E I 47 N 35 22 E I 33 N 42 I E -6 94 -6 94 -7 11 -7 48 -7 -7 -7 -5 -3 -1 77 92 56 78 40 51 0 O0 0 O0 0 o6 0 07 0 O8 0 23 I 22 0 48 0 56 0 O3 5 965 5 73 S 5 73 S 5 91 S 6 O1 S 5 91 S 5 23 S 3 03 S 0 30 S 1 91 N 646 E 7 75 E 8 86 E 9 97 E 11 12 E 12 61 E 14 52 E 16 85 E 18 75 E 20 52 E 8 79 S 47 19 E 9 10 11 12 13 15 17 18 20 64 S 53 29 E 55 S 57 8 E 59 S 59 19 E 64 S 61 37 E 92 S 64 52 E 44 S 7O 11E 12 S 79 48 E 75 $ 89 4 E 61 N 84 40 E 3000 O0 2999 72 2948 92 3100 3200 33OO 3400 3500 3600 3700 3800 O0 3099 O0 3199 O0 3299 O0 3399 O0 3499 O0 3599 O0 3699 O0 3798 69 3048 64 3148 58 3248 53 3348 47 3448 39 3548 05 3648 35 3747 3900 O0 3897.52 3846 89 84 78 73 67 59 25 55 72 1 26 N 46 53 E I 35 N 43 8 E I 54 N 27 23 E I 53 N 19 4 E 1 53 N 16 35 E I 54 N 15 52 E 3 13 N 8 24 E 6 7 N 1 48 W 7 6 N 4 5 W 7 49 N 5 57 W 0 01 1 43 3 68 6 49 9 43 12 40 16 02 23 98 35 69 48 5O 0 01 0 91 0 59 0 24 0 O0 0 O0 3 14 2 46 0 61 1 94 3 76 N 5 50 N 8 09 N 11 15 N 14 29 N 17 47 N 21.28 N 29.41N 41.17 N 53.98 N 22 35 E 24 16 E 25 98 E 27 24 E 28 23 E 29 15 E 3O O4 E 3O 36 E 29 67 E 28 63 E 22 66 N 8O 28 E 24 27 29 31 33 36 42 5O 61 78 N 77 10 E 21 N 72 42 E 44 N 67 45 E 64 N 63 9 E 98 N 59 4 E 82 N 54 41E 27 N 45 55 E 75 N 35 47 E 10 N 27 56 E COMPUTATION DATE: 8-NOV-92 PAGE 2 ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 2-NOV-92 KELLY BUSHING ELEVATION' 50.80 FI' ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3996 36 3945 56 9 46 N 11 17 W 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 4094 O0 4191 O0 4287 O0 4381 O0 4474 O0 4566 O0 4654 O0 4743 O0 4829 58 4043 79 4140 63 4236 86 4331 97 4424 10 4515 96 4604 35 4692 99 4779 78 12 2 N 10 35 W 82 99 15 I N 13 15 W 105 83 18 11 N 17 27 W 134 06 20 37 N 17 11 W 167 17 22 28 N 16 59 W 203 30 26 15 N 16 27 W 244 16 27 42 ' N 16 24 W 289 55 28 25 N 16 22 W 336 19 31 28 N 16 5 W 385 63 68 41 79 09 24 38 19 72 14 72 5000 O0 4914 54 4863 74 32 55 N 16 8 W 438 75 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4998 O0 5082 O0 5163 O0 5243 O0 5323 O0 5404 O0 5484 O0 5565 O0 5646 46 4947 05 5031 57 5112 74 5192 99 5273 31 5353 91 5434 77 5514 62 5595 66 32 54 N 16 7 W 492 25 34 16 N 14 44 W 547 77 36 23 N 13 37 W 605 94 36 47 N 13 26 W 664 19 36 37 N 12 38 W 724 51 36 27 N 11 43 W 783 11 36 6 N 11 32 W 842 97 35 58 N 11 3 W 901 82 36 14 N 11 I W 960 79 34 08 71 25 76 92 72 55 2 41 3 35 2 73 2 51 I 21 3 11 3 84 0 32 2 12 I 65 0 72 0 37 3 29 I 79 0 39 I 19 0 25 0 20 0 56 I 02 68 97 N 26 24 E 73 79 N 20 50 E 87 110 137 169 204 243 287 332 380 431 484 537 593 651 709 767 825 883 941 34 N 22 28 N 17 70 N 10 64 N 0 48 N 10 90 N 22 88 N 35 75 N 48 68 N 62 50 E 90 97 E 111 34 E 138 39 E 169 37 W 204 09 W 244 08 W 29O 25 W 336 18 W 385 19 N 14 27 E 74 N 9 15 E 08 N 4 18 E 64 N 0 8 E 74 N 2 54 W 90 N 5 11W 01 N 6 57 W 23 N 8 15 W 73 N 9 17 W 96 N 76 99 W 438 77 N 10 6 W 24 N 92 07 N 106 27 N 120 39 N 134 48 N 148 74 N 160 72 N 172 41N 184 18 N 195 03 W 492 83 W 547 82 W 605 77 W 665 40 W 724 82 W 784 72 W 843 29 W 902 48 W 961 90 N 10 46 W 59 N 11 15 W 45 N 11 31W 19 N 11 41W 83 N 11 49 W 40 N 11 50 W 59 N 11 49 W 43 N 11 47 W 26 N 11 44 W 6000 O0 5726 99 5676 19 36 35 N 11 55 W 1020 02 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5807 O0 5887 O0 5968 O0 6048 O0 6129 O0 6211 O0 6292 O0 6374 O0 6455 36 5756 85 5837 38 5917 98 5998 70 6078 07 6160 72 6241 48 6323 67 6404 56 36 25 N 11 46 W 1079 05 36 26 N 11 24 W 1138 58 36 18 N 11 25 W 1198 18 36 20 N 11 37 W 1257 90 35 50 N 11 22 W 1316 27 35 23 N 11 17 W 1374 92 35 9 N 11 14 W 1431 68 35 14 N 11 39 W 1489 87 36 8 N 12 36 W 1547 47 77 03 19 18 28 98 54 86 0 53 o 0 0 0 0 0 0 0 0 999 50'N 207 33 W 1020 77 N 11 43 W 26 1057 48 1115 57 1173 24 1231 84 1289 07 1346 23 1403 81 1459 88 1516 72 N 219 86 N 231 98 N 243 98 N 255 83 N 266 82 N 278 45 N 289 90 N 300 98 N 312 56 W 1080 46 W 1139 18 W 1198 O0 W 1258 76 W 1317 15 W 1375 38 W 1432 75 W 1490 98 W 1548 27 N 11 44 W 61 N 11 43 W 90 N 11 42 W 10 N 11 42 W 13 N 11 41W 24 N 11 40 W 97 N 11 39 W 56 N 11 38 W 93 N 11 39 W 7000 O0 6536 29 6485 49 36 24 N 13 19 W 1606 91 7300 7200 7300 7400 7500 7600 7700 7800 O0 6616 O0 6697 O0 6777 O0 6857 O0 6937 O0 7017 O0 7097 O0 7177 7900 O0 7257 73 6565 05 6646 21 6726 29 6806 22 6886 14 6966 10 7046 14 7126 18 7206 93 36 25 N 13 21 W 1666 25 36 41 N 13 31 W 1725 41 36 44 N 13 45 W 1785 49 36 52 N 13 38 W 1844 42 36 57 N 13 28 W 1904 34 36 58 N 13 13 W 1964 30 36 49 N 12 46 W 2024 34 36 50 N 12 4 W 2084 38 36 51 N 11 25 W 2144 18 62 26 99 92 91 85 71 61 0 36 1574 63 N 326 32 W 1608 08 N 11 42 W 01 1632 18 1690 31 1748 21 1806 21 1865 26 1923 25 1982 61 2040 42 2099 43 N 340 38 N 353 49 N 367 68 N 382 og N 396 58 N 410 10 N 423 63 N 436 32 N 448 O0 W 1667 81W 1727 90 W 1786 09 W 1846 15 W 1906 04 W 1966 55 W 2026 47 W 2086 64 W 2146 46 N 11 46 W 01 N 11 49 W 77 N 11 53 W 64 N 11 56 W 70 N 12 0 W 80 N 12 2 W 84 N 12 4 W 78 N 12 4 W 72 N 12 4 W ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE- 8-NOV-92 PAGE 3 DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE sUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARllJRE , MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/1OO FEET FEET FEET DEG 8000.00 7337.11 7286.31 37 4 N 10 45 w 2204 68 8100.00 7416.86 7366.06 37 9 N 10 6 w 2265 oo 8200.00 7496.46 7445.66 37 22 N 9 29 W 2325 54 8300.00 7575.83 7525.03 37 34 N 9 8 W 2386 37 8400.00 7655.01 7604 21 37 42 N 8 31 W 2447 44 8500.00 7733.99 7683 19 37 56 N 7 56 W 2508 75 8600.00 7812.96 7762 16 37 35 N 8 35 W 2570 09 8700.00 7892.26 7841 46 37 38 N 8 25 W 2631 O1 8800.00 7971.28 7920 48 38 3 N 7 24 W 2692 27 8900.00 8049.83 7999 03 38 18 N 6 40 W 2754 09 9000 O0 8128 53 8077 73 37 53 N 6 53 W 2815.72 9100 O0 8207 9200 O0 8288 9300 O0 8370 9400 O0 8456 9500 O0 8544 9600 O0 8633 9700.00 8725 9800.00 8816 9900.00 8907 82 8157.02 37 10 N 7 21 W 2876 59 13 8237.33 35 44 N 7 34 W 2936 87 8320.07 32 22 N 6 47 W 2992 64 8406.84 29 31 N 6 24 W 3043 38 8493.58 28 5 N 4 5 W 3091 86 8583.06 24 54 N 0 17 E 3135 06 8674.26 24 5 N I 50 E 3175 34 8765.54 24 11 N 2 18 E 3215 49 8856.69 24 25 N 2 20 E 3256 13 21 53 39 58 85 83 09 10000 O0 8998 40 8947 60 24 50 N 2 27 E 3296.86 10100 O0 9089 13 9038 33 24 49 N 3 7 E 3337.95 10200 O0 9179 81 9129 01 25 7 N 3 18 E 3379.07 10300 O0 9270 42 9219 62 24 48 N 3 0 E 3420.33 10400 O0 9361 52 9310 72 24 9 N 3 25 E 3460.58 10500 O0 9452 77 9401 97 24 9 N 3 25 E 3500.44 0 38 2158 29 N 460 20 W 2206 81 N 12 2 W 35 2217 28 2277 27 2337 65 2397 45 2458 09 2519 92 2579 77 2640 45 2701 63 N 471 29 N 481 32 N 491 67 N 500 37 N 509 11N 517 34 N 527 05 N 535 47 N 543 09 W 2267 35 W 2327 17 W 2388 57 W 2449 32 W 2510 98 W 2571 18 W 2632 59 W 2693 10 W 2755 11 N 12 0 W 61 N 11 56 W 37 N 11 52 W 36 N 11 48 W 58 N 11 42 W 81 N 11 37 W 66 N 11 33 W 83 N 11 28 W 52 N 11 22 W 0 62 2762 75 N 550 32 W 2817 02 N 11 16 W 0 2 3 2 3 3 0 0 0 82 2823 44 2882 33 2937 14 2989 26 3036 23 3081 46 3122 14 3163 59 3204 20 N 557 27 N 565 96 N 572 01N 578 78 N 583 34 N 584 35 N 583 15 N 581 25 N 580 87 W 2877 79 N 11 11W 63 W 2937 25 N 11 6 W 70 W 2993 25 N 11 2 W 53 W 3044 49 N 10 57 W 09 W 3092 25 N 10 52 W 50 W 3136 29 N 10 44 W 48 W 3176 40 N 10 35 W 91 W 3216.23 N 10 25 W 25 W 3256.36 N 10 16 W 0 43 3245.88 N 578.57 W 3297.04 N 10 6 W 0 32 3287.87 N 576.54 W 3338.04 N 9 57 W 0 30 3329.97 N 574.14 W 3379.10 N 9 47 W 0 37 3372.20 N 571.82 W 3420.34 N 9 37 W 0 O0 3413.41 N 569.46 W 3460.58 N 9 28 W 0 O0 3454.24 N 567.01 W 3500.46 N 9 19 W COMPLrrATION DATE: 8-NOV-g2 PAGE 4 ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 2-NOV-g2 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ INTERPOL~TEI) VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH '[RUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGU~R COORDINATES HORIZ. DEPAR]IJRE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0 O0 N 1000.00 999.99 949 2000.00 1999.96 1949 3000.00 2999.72 2948 4000 O0 3996.36 3945 5000 O0 4914.54 4863 6000 O0 5726.99 5676 7000 O0 6536.29 6485 8000 O0 7337.11 7286 9000 O0 8128.53 8077 19 0 14 S I 42 W -3 16 0 50 N 77 42 E -6 92 I 26 N 46 53 E 0 66 9 46 N 11 17 W 63 74 32 55 N 16 8 W 438 19 36 36 N 11 66 W 1020 49 36 24 N 13 19 W 1606 31 37 4 N 10 45 W 2204 73 37 53, N 6 53 W 2815 0.00 -50 80 0 0 N 0 0 E 0 O0 75 94 O1 68 75 02 91 68 72 0.00 3 0.00 0.01 3 2.41 68 0.72 431 0.53 999 0.36 1574 0.38 2158 0.62 2762 75 S 0 96 S 6 76 N 22 97 N 26 96 N 76 5O N 207 63 N 326 29 N 460 75 N 550 31E 3 46 E 8 35 E 22 24 E 73 99 W 438 33 W 1020 32 W 1608 20 W 2206 32 W 2817 0 O0 E 0 O0 N 0 0 E 76 S 4 47 E 79 S 47 19 E 66 N 80 28 E 79 N 20 50 E 77 N 10 § W 77 N 11 43 W 08 N 31 42 W 81 N 12 2 W 02 N 11 16 W 10000.00 8998.40 8947.60 24 50 N 2 27 E 3296.86 10500.00 9452.77 9401.97 24 9 N 3 25 E 3500.44 0.43 3245.88 N 578.57 W 3297.04 N 10 6 W 0.00 3454.24 N 567.01 W 3500.46 N 9 19 W COMPUTATION DATE' 8-NOV-92 PAGE 5 ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 2-NOV-g2 KELLY BUSHING ELEVATION' 50.80 FT ENGINEER' SCHWARTZ INTERPOL~TED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGU~R COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOLFTH EAST/WEST DIST. AZIMLFrH FEET DEG/iOO FEET FEET FEET DEG MIN 0 O0 50 80 150 80 25O 80 350 80 450 80 550 80 650.80 750.81 850.81 0 O0 50 80 150 80 25O 80 35O 8O 450 80 55O 80 650 80 750 80 850 80 -50.80 0 0 N 0 0 E 0.00 0 1 N 36 39 E 100.00 0 6 S 44 I E 200.00 0 7 S 19 42 W 300.00 0 8 S I 50 E 400.00 0 24 S 22 45 E 500.00 0 19 S 3 2 E 600.00 0 18 S 0 14 W 700.00 0 18 $ 3 35 W 800.00 0 18 S 3 33 W 0 O0 0 01 -0 08 -0 21 -0 41 -0 89 -1 50 -2 01 -2 55 -3 06 0 O0 0 46 0 13 0 O0 0 15 0 O0 0 O0 0 O0 0 O0 0 O0 0.00 N 0.01 N 0 06 S 0 19 S 0405 0 87 S 145 S I 97 S 2 52 S 3055 0 O0 E 0 01 E 0 13 E 0 13 E 0 09 E 0 24 E 0 41E 041 E 040 E 0 36 E O oo N O O E 01 N 31 0 E 14 S 65 9 E 23 S 34 41E 41 S 12 49 E 90 S 15 33 E 51 S 15 55 E 02 S 11 52 E 55 S 8 57 E 07 S 6 48 E 950.81 950.80 900.00 1050.81 1050.80 1000 O0 1150.81 1150.80 1100 1250.81 1250.80 1200 1350 81 1350.80 1300 1450 81 1450.80 1400 1550 82 1550.80 1500 1650 82 1650.80 1600 1750 82 1750.80 1700 1850 83 1850.80 1800 O0 O0 O0 O0 O0 O0 O0 O0 0 16 S 3 47W 010 S 6 3W 0 14 S 10 40 E 0 21 S 33 19 E 0 17 S 60 33 E 0 20 S 58 29 E 0 17 S 69 18 E 0 31 S 67 49 E 0 35 S 78 24 E 0 42 N 88 49 E -3 54 -3 92 -4 27 -4 79 -5 23 -5 58 -5 89 -6 19 -6 62 -6 90 0 O0 0 O0 0 2O 0 O0 0 04 0 O0 0 O0 0 18 0 01 0 01 3.53 S 3.92 S 4.28 S 4.77 S 5 14 S 543 S 5 66 S 5 88S 6 15 S 6265 0.33 E 0.31 E 0.30 E 0.51 E 0.92 E 1.37 E 1.85 E 2.41 E 3.35 E 4.41 E 355 S 5 17 E 93 S 4 30 E 29 S 3 57 E 80 S 6 9 E 23 S 10 10 E 60 S 14 11E 95 S 18 8 E 35 S 22 18 E O0 S 28 34 E 66 $ 35 9 E 1950 84 1950.80 1900 O0 2050 2150 2250 2350 2450 2550 2650 2750 2851 85 2050 80 2000 85 2150 86 2250 87 2350 87 2450 89 2550 93 2650 98 2750 03 2850 80 2100 80 2200 80 2300 80 2400 80 2500 80 2600 80 2700 80 2800 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 51 N 79 24'E 0 45 N 79 33 E 0 37 N 89 23 E 0 39 S 79 41 E 0 40 S 85 21 E 0 52 N 86 49 E I 7 N 72 17 E I 54 N 45 44 E I 56 N 34 2 E I 36 N 38 53 E -6 97 -6 92 -6 99 -7 30 -7 64 -7 87 -7 86 -6 81 -4 55 -2 37 0 03 0 29 0 18 0 16 0 03 0 20 1 05 0 64 0 09 0 23 6 lOS 581 S 5 69 S 5825 5 985 5 99S 5 71 S 4 27 S 1 62 S 0 89 N 5 75 E 7 15 E 8 33 E 9 43 E 10 52 E 11 83 E 13 47 E 15 75 E 17 85 E 19 65 E 8 39 S 43 19 E g 10 11 12 13 14 16 17 19 21 S 50 52 E 09 S 55 38 E 08 S 58 2O E 10 S 6O 23 E 26 S 63 8 E 64 S 67 I E 32 S 74 50 E 92 S 84 48 E 67 N 87 24 E 2951 07 2950.80 2900 O0 3051 3151 3251 3351 3451 3551 3651 3752 3852 10 3050.80 3000 14 3150.80 3100 19 3250.80 3200 25 3350.80 3300 30 3450.80 3400 36 3550.80 3500 $3 3650.80 3600 09 3750.80 3700 87 3850.80 3800 O0 O0 O0 O0 O0 O0 O0 O0 O0 I 29 N 45 14 E I 25 N 46 18 E I 51 N 35 14 E I 56 N22 1 E I 53 N 17 4 E I 54 N 16 12 E 2 6 N 14 40 E 444 N 2 6 E 6 ,53 N 3 39 W 7 22 N 4 34 W -0 70 0 71 2 46 5 10 7 99 10 95 14 O0 19 47 29 90 42 33 0 O0 0 O0 0 56 0 36 0 O0 0 O0 0 80 2 87 0 68 0 49 2 89 N 4 62 N 6 71N n 65 N 12 75 N 15 92 N 19 16 N 24 83 N 35 36 N 47 81N 21 45 E 23 27 E 25 13 E 26 67 E 27 77 E 28 70 E 29 61E 30 34 E 30 07 E 29 18 E 21 65 N 82 20 E 23 26 28 3O 32 35 39 46 56 73 N 78 46 E 01 N 75 3 E 37 N 70 7 E 56 N 65 2O E 82 N 6O 59 E 27 N 57 5 E 21 N 5O 42 E 42 N 4O 22 E 01 N 31 24 E COMPUTATION DATE: 8-NOV-92 PAGE 6 ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SLI3-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTLF{E MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 3953 84 3950.80 3900.00 8 43 N g 17 W 4055 4157 4261 4366 4473 4582 4695 4808 4924 34 4050.80 4000.00 10 51 N 11 54 W 73 69 4150.80 4100 O0 13 47 N 10 51 W 95 38 4250.80 4200 O0 16 55 N 16 6 W 122 87 4350.80 4300 O0 20 6 N 17 9 W 155 92 4450.80 4400 O0 21 46 N 17 10 W 193 98 4550.80 4500 O0 25 36 N 16 26 W 236 30 4650.80 4600 O0 27 42 N 16 25 W 287 47 4750.80 4700 O0 28 36 N 16 21 W 340 47 4850.80 4800 O0 31 52 N 16 4 W 398 56 22 57 3O 56 81 66 79 55 14 50 1 81 I 95 3 31 4 06 I 99 2 41 4 37 0 25 2 46 I 61 61 64 N 27.59 E 67.53 N 24 7 E 78 100 126 158 195 236 285 336 393 66 N 24.23 E 82.31 N 17 7 E 01 N 20.17 E 102.02 N 11 24 E 57 N 13.69 E 127.31 N 6 10 E 62 N 3 80 E 158.67 N I 22 E 11N 7 49 W 195.25 N 2 12 W 74 N 19 98 W 237.58 N 4 49 W 78 N 34 46 W 287.86 N 6 53 W 61 N 49 38 W 340.21 N 8 21 W 04 N 65 73 W 398.50 N 9 30 W 5043.21 4950 80 4900.00 32 59 N 16 I W 462 10 5162.41 5050 80 5000.00 33 17 N 15 38 W 526 56 5284.19 5150 80 5100.00 36 6 N 13 40 W 595 78 5408.81 5250 80 5200.00 36 44 N 13 27 W 669 97 5533.40 5350 80 5300.00 36 37 N 12 7 W 744 15 5657.74 5450 80 5400.00 36 16 N 11 34 W 817 98 5781.50 5550.80 5500.00 35 58 N 11 8 W 890 86 5905.18 5650.80 5600.00 36 17 N 11 2 W 963 60 6029.64 5750.80 5700.00 36 32 N 11 55 W 1037 66 6153.96 5850.80 5800.00 36 23 N 11 34 W 1111.47 0 24 2 32 I 85 0 54 0 84 0 53 0 85 1 O7 0 0 454.55 N 83.48 W 462 15 N 10 24 W 516.92 N 101.36 W 526 584.20 N 118.62 W 596 656.52 N 135.99 W 670 728.94 N 152.67 W 744 801.27 N 167.73 W 818 872.74 N 182.19 W 891 944.18 N 196.06 W 964 27 1016.77 N 210.97 W 1038 44 1089.08 N 226.04 W 1112 76 N 11 6 W 12 N 11 29 W 45 N 11 42 W 76 N 11 50 W 64 N 11 49 W 56 N 11 47 W 32 N 11 44 W 43 N 11 43 W 29 N 11 44 W 6278.18 5950.80 5900.00 36 20 N 11 25 W 1185 11 6402.26 6050.80 6000.00 36 20 N 11 37 W 1258 53 6526.00 6150.80 6100.00 35 38 N 11 19 W 1331 36 6648.70 6250.80 6200.00 35 16 N 11 12 W 1402 43 6771.03 6350.80 6300.00 35 8 N 11 28 W 1472 85 6893.97 6450.80 6400.00 36 6 N 12 31 W 1544 31 7018.03 6550.80 6500.00 36 27 N 13 20 W 1617 59 7142.37 6650.80 6600.00 36 32 N 13 23 W 1691.31 7267.05 6750.80 6700.00 36 44 N 13 41 W 1765.60 7391.89 6850.80 6800.00 36 52 N 13 39 W 1840.14 0.38 1161 31 N 240 62 W 1185 97 N 11 42 W 0.25 1233 30 N 255 0.74 1304 71 N 269 0.56 1374 45 N 283 0.39 1443 55 N 297 0.91 1513 52 N 312 0.23 1585 04 N 328 0.52 1656 94 N 345 0.27 1729.34 N 363 0.19 1801.95 N 380 27 W 1259 75 W 1332 64 W 1403 41W 1473 21W 1545 78 W 1618 82 W 1692 23 W 1767 94 W 1841 44 N 11 42 W 31 N 11 41W 41 N 11 40 W 86 N 11 38 W 38 N 11 39 W 78 N 11 43 W 64 N 11 47 W 08 N 11 52 W 78 N 11 56 W 7516.99 6950 80 6900.00 36 57 N 13 27 W 1915 11 7642.12 7050 7767.09 7150 7892.02 7250 8017.15 7350 8142.60 7450 8268.44 7550 8394.68 7650 8521.31 7750 8647.70 7850 80 7000.00 36 56 N 13 2 W 1990 80 7100.00 36 51 N 12 22 W 2065 80 7200.00 36 51 N 11 27 W 2139 80 7300.00 37 5 N 10 38 W 2215 80 7400.00 37 14 N 9 48 W 2290 80 7500.00 37 30 N 9 14 W 2367 80 7600.00 37 42 N 8 33 W 2444 80 7700.00 37 57 N 7 54 W 2521 80 7800.00 37 29 N 8 51W 2599 17 , O0 82 02 75 14 18 85 14 0.25 1875.02 N 398.53 W 1916.91 N 12 0 W 0.36 1948 23 N 415.79 W 1992.11 N 12 3 W 0.53 2021 0 46 2094 0 40 2168 0 59 2242 0 29 2318 0 61 2394 0 51 2471 0 34 N 432.30 W 2067.05 N 12 4 W 63 N 447.69 W 2141.94 N 12 4 W 45 N 462 10 W 2217.15 N 12 2 W 99 N 475 54 W 2292.85 N 11 58 W 34 N 488 11 W 2369.16 N 11 53 W 45 N 500 09 W 2446.11 N 11 48 W 35 N 511 12 W 2523.65 N 11 41 W 46 2547.83 N 522 39 W 2600.83 N 11 35 W -) COMPLri'ATION DATE: 8-NOV-g2 PaGE 7 ARCO ALASKA INCo P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA DA'lIE OF SURVEY: 2-NOV-92 KFIIY BUSHING ELEVATION: 50.80 F'I' ENGINEER: SCHWARTZ INTERPOLATEI) VALUE FOR EVEN 100 FEET OF SLN~-SE.A DEPTH 3'RUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTI~E MEASUR~ VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST° AZIMUTH DEPTH DEPTH DEPTH DEe MIN DEG MIN FEET .DEG/IO0 FEET FEET FEET DEG MIN 8774 04 7950.80 7900.00 37 53 N 7 39 W 2676 32 8901 9028 9153 9276 9393 9507 9618 9728 9837 24 8050.80 8000.00 38 18 N 6 39 W 2754 18 8150.80 8100.00 37 42 N 7 I W 2832 76 8250.80 8200 O0 36 37 N 7 34 W 2908 09 8350.80 8300 O0 33 13 N 7 0 W 2979 27 8450.80 8400 O0 29 40 N 6 26 W 3040 28 8550.80 8500 O0 27 58 N 3 46 W 3094 65 8650.80 8600 O0 24 25 N 0 59 E 3143 20 8750.80 8700 O0 24 6 N 2 3 E 3187 78 8850.80 8800 O0 24 16 N 2 16 E 3231 86 97 87 23 21 80 27 13 O1 0.89 2624.23 N 533 49 W 2677 90 N 11 29 W 0.45 2702 23 N 543 0 85 2779 I 25 2855 3 79 2925 2 29 2985 4 49 3040 2 76 3089 0 51 3133 0 39 3178 lg W 2756 89 N 552 41 W 2834 24 N 562 05 W 2910 06 N 571 13 W 2980 70 N 578 16 W 3041 19 N 583 33 W 3095 15 N 584,44 W 3143 85 N 583.09 W 3187 64 N 581.30 W 3231 29 N 11 22 W 24 N 11 14 W 03 N 11 8 W 29 N 11 3 W 17 N 10 58 W 65 N 10 52 W 95 N 10 43 W 64 N 10 32 W 36 N 10 22 W 9947 60 8950 80 8900.00 24 36 N 2 15 E 3275.42 10057 76 9050 80 9000.00 24 53 N 2 48 E 3320,62 10167 98 9150 80 9100,00 '25 0 N 3 19 E 3365.84 10278 37 9250 80 9200.00 24 55 N 3 3 E 3411.46 10388 25 9350 80 9300.00 24 9 N 3 25 E 3455.90 10497 84 9450 80 9400,00 24 9 N 3 25 E 3499.58 10500 O0 9452 77 9401.97 24 9 N 3 25 E 3500.44 0 39 3223 98 N 579.46 W 3275.64 N 10 11 W 0 30 3270 15 N 577.46 W 3320.74 N 10 1 W 0 52 3316 43 N 574.92 W 3365.89 N 9 SO W 0 54 3363 12 N 572.30 W 3411.47 N 9 39 W 0 O0 3408 61 N 569.74 W 3455.90 N 9 29 W 0 O0 3453 35 N 567,07 W 3499.60 N 9 20 W 0 O0 3454 24 N 567.01 W 3500.46 N 9 19 W ARCO ALASKA INCo P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA MARKER LAST READING GCT TD COMPUTATION DATE: 8-NOV-g2 PAGE 8 DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1384' FSL & 908' FEL, SEC16 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10371.10 9335.16 9284.36 3401.56 N 570.19 W 10500.00 9452.77 9401.97 3454.24 N 567.01 W ARCO ALASKA INC. P1-20 POINT MCINTYRE NORTH SLOPE, ALASKA MARKER LAST READING GCT TI) COMPUTATION DATE: 8-NOV-g2 PAGE 9 DATE OF SURVEY: 2-NOV-92 KELLY BUSHING ELEVATION: 50.80 FT ENGINEER: SCHWARTZ *****~**~*** STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 1384~ FSL & 908~ FEL, SECI$ T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB , FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10371.10 9335.16 9284.36 3401.56 N 570.19 W 10500.00 9452.77 9401.97 3454.24 N $67.01W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10S00.00 9452.77 9401.97 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3500.46 N 9 19 W DIRECTIONAL SURVEY come, man, ARCO ~ INC. ~.~.u:~ POINT MCIN'T'YRE ~ P1-20 co~'m~ USA .u. ONE ~'mt.oe,~ 0~ - NOV - 92 ~ uxb? 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'": ...... i ...... .'-': ..... .' : ; . : : : - ; ; : : ; [ : i , : : : : ~ : ~ ; ~L.: : · ~ ; : · ~. ~...~. ~ ..... ~ .... :..~ ~.-.~.-:...~-.~...-:...:...;..-' ....... ARCO Alaska, Inc. Lisburne/Point Mclntyre Engineering Date: December 30, 1992 Subject: Transmittal #248, P1-20 From' ARCO Alaska Inc. To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point Mclntyre Well P1-20 data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. MAC Acoustic Filtered Waveforms /'" LWD CDR-TVD / LWD CDR-MD ~' LWD CDN-TVD LWD CDN -MD -- Log 1 blue line, 1 sepia Gyro Continuous Survey '/ 1 Dual Induction-Gamma Ray-~ 1 Sub-Sea Vertical Depth (Single Shot Data) ~" 1 Z-Densilog Cmpnstd NEUTRON -GR-Caliper ~' 1 Borehole Profile -- 1 MAC Gamma Ray Correlation "~ 1 Segmented Bond Log, 9 s/0" & 7" Casing / 1 Borehole Cmpnstd MAC Computed Slowness Curves 1 cmpst cmpst cmpst cmpst Run # Run Date Company 11/02/92 10/29/92 10/29/92 10/29/92 10/29/92 10/29/92 11/16/92 10/29/92 10/29/92 10/29/92 10/29/92 10/29/92 10/29/92 Schlumberger Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Schlumberger Schlumberger Schlumberger Schlumberger D APE/DISKETTE w/printout iskette, Complete Calculated GCT (n,o printout) -'"OH Edit Tape, LWD Bit Runs 1-3 ,~ .¢9' ~) /LIS Tape, Anadrill Advisor ~ ,.¢' q' ~ 9 / LIS Tape, MAC Waveforms ~ d"~/~3'" Run # 1 1-3 Run Date 11/2/92 10/29/92 10/29/92 10/29/92 Company Schlumberger Schlumberger Schlumberger Schlumberger Please sign and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 RECEIVED DEC ~ I 1992 Alaska 011 & (~ms Cons. Commission Anchorage Transmittal #248 PLEASE SIGN ONE COPY AND RETURN ARCO Alaska, Inc. Post Office B~ ;)360 Anchorage AI&;;Ka 99510;0360 Telephone 907 276 1215 TO: STATE of ALASKA OIL/GAS CONSER. COMM. 3001 PORCUPINE ANCHORAGE, ALASKA OPERATOR: ARCO , SAMPLE TYP '~D~IES~ SAMPLES SENT: DRIES: DATE: ~NOVEMBER, 1992 AIRBILL: AL 646248 AFT#: 2-11-O~- CHARGE CODE: 2C0009 NAME: P1-20 NUMBER OF BOXES: 7 6460'-7540' 7540'-8710' 8710'-9270' 9270'-9570' 9570'-9880' 9880'-10190' 10200'-10500' SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: ARCO ALASKA, INC. BAYVlEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 .~~ ATTN: D. L. Przywojskl ABV-100 NOV 2 0 1992 AJa,..~ka Oil & Gas Co~. CommbsJon ARCO Alaska, inc. is a Subsidiary of Atlantic Richfield Company AOGCC GEOLOGICAL MATERIALS INVENTORY LIST COMPLETION DATE t~ I.. ~, ~-~ CO. CONTACT ~ [~1~- ' 'check' off oriist data as it' i'~ receiVed.*list recei~/ed date for 407. if not required Ii'st as NR 4oz I* = Iii !~-~ ..... d,',,,n" idstofi' V' "' su~e~l'~ ! well tests" ~ ! ~ore descrirtiO'~ ~ cored inte~als core .~nal~i.s ~ d~ ditch inte~als digital data ~~"_ ,,,, .......~ ~ & ~','~/~ ~,'~,, ,' ,, '~~, '~ ~o~'~ .......... ~,~ ,,~ ,, ...................... ~~ ~ LOG TYPE RUN INTERVALS ' SCALE _ . .... NO. [to the nearest foot) [incht! O.O,). ~ ~c/m,, ,~, I c~, ............ v--~ ,, qo?~--tc~' ,, ~,~ 1 31 ~..l., \ ~ x:),--- I, b %'? ~ .--- ~1 . i i i i i iii i i ii i i iii i i i i i 14! Jl I .I i i LJ LIII I II II I I I II LIL i iii ii i , L ~ , · Lll I III I I I Illllllll I I IIII I I I II I II III I I I I I II I III I I I I I I I I II I I I II III I1 BP EXPLORATION AR~ J Alaska, Inc. September Z2, 1992 Mr, Mike Mendor Alaska Oil and Gas ConServation Commission 3001 Porcupine Dr. ~ Anchorage, AK 99501 Subject: P1-20 West Sak Isolation Dear Mike: With regard to well planning for Pt. Mclntyre Pt-20, we anticipate encounturing the West Sak top @ .r6620 TVD SS. While the West Sak is regarded as the shallowest potential reservoir, absence of significant hydrocarbon shows in the west Sak at Pt, Mctntym. Well 8 and l 1 indicate significant shows of hydrocart:)(m Occurrence is unlikely in P1-20. We wilt confirm this with both mwd and mud=togs, If hydrocarbons are encountered, a lead slurry of Haliburton (econolite) cement will be used to cover uppermost hydrocarbon. ,Sincerely, Tommy Johnson Rig Supervisor, PBD cc: Mike Zanghi Pi-20 Well File RECEIVED S E P 2 2 1992 Alaska Oil & Gas Cons. CommisSiOn Anchorage BP EXploration (Alaska) Pest Office Box 196612 An~horagu, Alaska 9951 Telephone (907) 561-511 ......... Co-Ope.raters., Prudhoe Bay Unit .ARCO Afa. ska, lnc, Post OffinP. Ro× 100360 Anchorage, Alaska 99510-0360 Telephone t907) 276.1215 ALASKA OIL AND GAS CONSERVATION COMMISSION September 25, 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 'WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Point McIntyre P1-20 ARCO Alaska, Inc. Permit No: 92-94 Sur. Loc. 1384'NSL, 908'WEL, Sec. 16, T12N, R14E, UM Btmhole Loc. 632'SNL, 1572'WEL, Sec. 16, T12N, R14E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~g~.% pdnted on recycled paper b y C D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill E]llb. Type of well. ExploratoryF'l Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 52'feet Pt. Mclntyre 3. Address 6. Property Designation P. O. Box 196612. Anchorage. Alaska 99519-6612 ADL 28297 4. Location of well at surfaCe 7. Unit or property Name 11. Type Bond(see 20 ^^c 25,025) 1384' NSL, 908' WEL, SEC. 16, T12N, R14E, UM Point Mclntyre At top of productive interval 8. Well number Number 903' SNL, 1517' WEL, SEC. 16, T12N, R14E, UM P1-20 U-630610 At total depth 9. Approximate spud date Amount 632'SNL, 1572'WEL, SEC. 16, T12N, R14E, UM 9/30/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 34622/632 feet PM- 12/75 feet 2560 10399'MD/9411'TVD~eet 16. To be completed for deviated wells !17. Anticipated pressure (s~e 20 AAC 25.035 (e)(2)) Kickoff depth 35oofeet Maximum hole angle3~.~70 Maximum surface 3330pslg At total depth (TVD) 8800'/4390pslg 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) 30" 20" 94.5# H-40 Weld 72' 38' 38' 110' 110' 245 cu ft CS II 16" 13-3/8" 68# L-80 BTC 3463' 37' 37' 3500' 3500' 2552 cu ft CS 111/460 cu fl "G" 12-1/4" 9-5/8" 47# L-80 NSCC 9555' 36' 36° 9591' 8652' 440 cu fl Class "G" 8-1/2" 7" 26# 13CR Fox 1108' 929 I' 8487' 10399' 9411' 241 cu ft Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ECEIYED Surface Intermediate Production q ~'r~ 'I 5 1992 Liner AJaska Oil & Gas Co:ts. Co;nm~sstol, Perforation depth: measured Allch0rage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify ~hat_the/foregoing~~ is true and correct to the best of my knowledge e~.._/,~;~ ~ Signed - Title Drilling Engineer Supervisor Ddt Commission Use Only Permit Number IAPI number IApproval date See cover letter ~'.~_- ,~ ~' 15 0- 0.2_ ~' --- 2_ ~. ~., <~ ~' I ~ '" ~',¢~'~' ~'~ for other requirements Conditions of approval Samples rec[uir.ed [] Yes '~rNo Mud Icg required, [] Yes ~ No Hydrogen sulfide measures [] Yes ~I~ No Directional survey requ~re~ ~ Yes [] No Required working pressure for BOPE' []2M; 1-13M; /[~5M; r-I10M; r-115M; Other: by order of Approved by Commissioner ~ne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate PF~UDHO[ SAY DF~IF-X}MG POINT McINTYRE WELL ?1-~0 TPavellin9 CylindeP - No, mol Plane Re£e~ence Well- Pi-~O TVD 0 - 934~ £~c, In±e~val, 50 £~, ALL DiPec~cions Rel ~co TPue Nop~ch ~70o 300° 240° 2]0° lBOo I ]80° ]E,Oo BHL TVD 9341.51 MD 10155.6~2 VS 3055.89 Nop -t:h ~'970.74 West 716.39 dhoe Bay Dr. .ng Point McIntyre Well' #P1-20 REVISED' 08 SEPTEMBER 1992 0-- 5O0-- lO0O~ 1500--- PO00~ 2500-- 3000~ 35001 VERTICAL VIEW SCALE 500 Ft, / DIVISION o.oo' I~ o HD R.K.B. ELEVAT)DN (52.0' ABOVE SEA LEVEL) SURFACE LOCATION, ASP-X, 674149.29 ASP-Y, 5994510.23 ' TARGET LOCATIDN, ASP-X, 673470.98 ASP-Y, 5997488.08 BOTTOM B\HOLE LOCATION, ASP-X, 673409.64 ASP-Y, 5997757.41 0.'00~ @ 3500 MD KDP 13.375 OD, e 3500 MD, 3500 TVD 4.00' e 3700 MD 8,00' E 3900 MD 12.00' @ 4100 MD 16 00' @ 4300 MD 20.00' 8 4500 MD 24.00' ~ 4700 ND 28.00' ~ 4900 MD 32.00' @ 5100 MD 36.00' @ 5300 MB 37.70' 8 5385 MD END OF ~UILD lOO, 9000-- 9317 9412 9500-- loooo 2629 3054 3330 ( ,ISMITHg]O( HERIZFINTAL VIEW (TRUE NORTH) SCALE 500 Ft, / DIVISION 3500 · t 3A8.50' - 9A~ i 3AB '50' . . 3~8,50' 9940 3,~B .50' ~ B~Bt - 3~8'5~ ~ ~tZ7 - 348,5( ~ ~o C .,~o' ~500 ~000 ~] 000 3~~ .5~' 5~58 - _ 3~, ~756 ' 3 48' 50' 3 I o 500 0 37.70' e 8706 MD START DF DRDP 33.70' ~ 8906 MD 29.70' @ 9106 MD 25.70' e 9306 MD 21.70' ~ 9506 MD EAS)NG 9,625 OD, e 9591 MD, 8652 TVD END OF DROP 20.00' e 9591 MD TARGET - KUPARUK 20.00' ~ 10299 MD HILUVEACN 20.00' ~ 10399 MD TOTAL DEPTH 348,50° 0 500 1000 1500 2000 2500 3000 3500 4000 VERTICAL SECTION PLANE: 3HL TVD 9410.97 MD 10398.93 VS 3330,49 North 3263.64 We$~ 663.98 Pt. Mc Intyre P1-20 Casing Design Specifications SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) TJYS (#) 1069000 1300000 1556000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) Si PRESSURE 1 4 3500 2548 Burst S.F. 1.35 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3500 1729 Collapse S.F. 1.31 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 3861 PBYS Tension S.F. 4.76 Mud Wt. 9.5 ppg TJYS 5.79 String Wt. (#) 224426 Pt. Mc intyre P1-20 Casing Design Specifications Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 3420 Burst S.F. 2.01 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 8605 0.1 3704 Collapse S.F. 1.28 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 9297 PBYS Tension S.F. 2.94 Mud Wt. 10.2 TJYS 3.15 String Wt. (#) 368837 Pt. Mc Intyre P1-20 Casing Design Specifications PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 460000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 351 2 3420 2.06 Burst S.F. Collapse Calculation Collapse rating baSed on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Gas Grad. TVD (FT) (psi/ft) Collapse Press 8605 0.1 3704 1.46 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 1152 Mud Wt. String Wt. (#) 10.2 25282 Tension S.F. PBYS TJYS 18.19 26.38 MUD PROGRAM - P1-20 SPUD MUD PROPERTIES Density Marsh Vis Yield Pt. 10 sec gel Spud 8.7 300 40-60 30-60 TD 9.5 1 oo 20-40 15-20 INTERMEDIATE HOLE MUD PROPERTIES: Surface casing shoe to Top 'K-10' shale (8251 ss): Mud Weight Yield Point 10 sec Gel 10 rain Gel 9.5 - 10.0 10 - 15 5 - 10 10 - 20 Top 'K' shale to Section TD. Mud Weight Yield Point 10 sec Gel 10 min Gel 9.5 - 10.5 10 - 20 5 - 10 15 - 25 PRODUCTION HOLE/ CORING FLUID PROPERTIES Weight PV YP 10 sec Gel 9.8-10.2 15-20 7-12 5-9 10 min gel pH 60-80 9-10 20-30 9-10 APl F.L. 15-25 15-25 Hardness <200 <200 APl Fluid Loss pH Hardness <12 9.5 - 10.0 < 200 APl Fluid Loss pH Hardness 6.0 - 8.0 9.5 - 10.0 < 200 10 min Gel HTHP F.L. 1 5-20 _<2cc E.S. 2000 PM1-20 Operations Summary 1. MIRU drilling rig. 2. Spud well and drill 16" hole MWD directional to 3500'tvd/3500'md. . Set 13 3/8" casing and cement same. Test casing to 2500 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. . Pick up 12 1/4" BHA and drill 10' of new hole and perform leakoff test. Continue drilling MWD directional to 8605'tvd/9297'md. Mud log from 7000' tvd. DPR Gamma / Resistivity by K-10. Open hole log DIFL/SFL/SP/GR/BHC Sonic 5. Set 9 5/8" casing and cement same. . PU 8 1/2" BHA and test casing to 3000 psi. Drill 10' of new hole and perform formation integrity test to12.5 ppg EMW..Drill to core point. In this well core point should be immediatly following FIT test below the 9-5/8" shoe. . Core ( 4" oriented) through the kuparuk sands to 50' TVD below WOC (9069' SS 9121 TVD) and drill 8 1/2" hole to 9332'tvd/10149'md. Run open hole logs. 8. Set 7" liner at 9332'tvd/10149'md and cement same. Clean out 9 5/8" casing. 9. PU 6" BHA and clean out 7" liner; test to 3000 psi for 30 minutes. 10. Circulate well to 9.8 ppg brine. Run cased hole logs. Freeze protect well with 2000' of diesel. NU dry hole tree and test to 3000 psi. Release rig. 11. Run tubing string at later date with workover rig. a. Excess non-hazardous fluids developed from well operations should be pumped down the 13 3/8" x 9 5/8" annulus of Pi-ll. The annulus will be left with a non-freezing fluid during any extended period. b. Wells within 200' of the proposed well are: c. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. d. The maximum surface pressure is based upon the BHP and a full column of gas to surface. e. Based upon previous logs obtained from PM wells, no productive zones are anticipated above 7000'tvd. f. No hazardous levels of H2S are anticipated in this well. However, H2S qualified personnel and suitable precaution will be used in the drilling of this well. PRUDHOE BAY DRILLING G, ,OUP 20" DIVERTER SCHEMATIC POOL 7 FILL UP LINE FLOWLINE 2O" 2O0O PSi DIVERTER 10" BALL VALVE CONDucToR 10" BALL VALVE NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS"CONDITIONS REQUIRE THE USE OF THE SECOND DIVERTER LINE. THE SECOND VENT LINE CAN BE REMOTELY OPENED TO ACHIEVE DOWNWIND DIVERSION. THIS IS A VARIANCE FROM 20AAC25.035. HYDRIL 13 5/8"-5000PSl OK ANNULAR BOP LATCHED HEAD CONNECTION'5 5/8'-10,000PSl HUB BOT~Olvf HYDRIL 15 5/E'- 10, O00PSi /,,fPL ~ BOP HUB CONN£CT/ONS 4. I/1¢'-10,000PS! SIDE OUTLETS HYDRIL 73 5/8'-10,000PSl /vl'PL RAM BOP HUB CONNECTIONS 4. ~/'1¢'-~0,000PS! SIDE OLTTLETS CHOKE WING HCR 14ANUAL MANUAL LYNN INTIERNA'TIONAL. ~ ~/~6'-~o, oooPs~ CHECK VALVE KILL WING t4c~OY 4. 1/16'-10 TYPE' E 6'AT'E VALV~ /vfcEVOY 5 1/1¢'-10,000PSi Tr'PE E CATE VAL~ HYDRIL 13 5/8"- 10, O00PSI f IvfPL PJJ, f BOP HUB CONNECTIONS j 4. ~/~6'-IO, O00PSI SIDE OUTLETS .. ~ ~ 5/¢'-1O, oooP.sl HUB X FLANGE ~o~o~ R E C E IV E D AU G 2 0 1992 Alaska Oil & Gas Cons. uu~m~issiUn Anchorage BLOW-OUT PREVENTER STACK PM RIG 7. I"~I"~,J.~IIViiI~I/-~I-[ Y VVI"LL I"'L/-~i~I_~. ELL P1-20 PBU 20" Conductor 13-3/8" 68# L-80 BTC Casing 16" hole KOP 35O0' 7" Liner Hanged Packer/Tieback Assembly 9-5/8" 47# L-80 NS-CC Casing shoe 12 1/4" Open Hole 8 1/2" PBTD 7" 26# 13-Cr Fox Liner shoe 8 1/2" Open Hole PROPOSED DEPTH MD/BKB 117' 3500'TVD 3500'MD 9147' MD 8605' TVD 9297' MD 10069' MD 9332' TVD 10149' MD · 5,,~l~te.. :: Al as ka ~¥~1111:: PI,,.?,.,CI IF:::~.:dd :: Pt. Molntyre. 9/17/92 M, Minder Casing Iht Iht Size E:h~.tto rr~ Top ~ A 2O 110 38 2A 13.375 66 3'7 8A 1 d.3 7~ 3:~00 ~ 03 4A 9.625 8652 36 5A 7 94.11 84,87 6A 0 0 0 7A 0 0 0 8A 0 0 9A 0 0 0 10A a 0 0 Deso Length Lbs 7~ 94.5 66 68 3397 68 9555 4.7 'f 'f 08 ;~6 0 0 0 0 0 0 0 0 0 0 Desa [:)~,:,sa Tension Grade Thread I.,,.bs H,,,40 Weld () K...55 EI"FC 0 [..~.8() E]'T'C 0 L,:,,80 NSC:X: 0 'f 3(:.:1::~ F'ox 0 0 0 0 0 () 0 0 0 o 0 0 0 0 0 0 2B 3B 5[,',4 6B 7B 8B 10B Mud Hyd Wieght G. ra<iier~t ppg. psi/ft 9.5 0.4,94. 9.5 0.4.94. 9.5 0,4.94. 10.5 (3.54.6 10,2 0.530 C1.0 0.000 0,0 0,000 C!. 0. 0.0CiCI 0,0 0,000 0.0 0.000 NtA Press Minimum p si Yi eld R]IDIt:::: 0 8330 3460 'I ..0 3330 5020 I ,.5 8'7 '18 6870 1. ~ 3'718 '724,O 1.9 0 () 0 0 1C 2C.: 4,C: 5¢:: 6C '70 8C: 9C 10C "f'er~sion Str'er'~gth I</L,bs t(/L.bs 6.804. 0 4,. 4.88 'f 069 2'30,996 '? 556 449.085 1086 28,808 604. 0 0 0 0 I::~r'(.~s s ur'~:,~ Collapse [,]ot,,,F:~SIResist, OIl)IF::: 54. '33 't 950 ~9..809 1729 2260 I., ~O'7 4,724. 4,'750 4992 544 0 'I ,,0~4 0 0 # DttV~O~ 0 0 o/4. ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE ['2 thru (3) Admin ~i3]-'~/~</~- [ 10 g 13] [14 thru 22] (5) BOPE ,'~)'./.~/'~.'~ 9-}7-~ [23 thru 28] (~') Other [29 thru 31] ~- ' g323 (8) Addl /~,,.,~../~.. ~/o/7-~/~ en9 i nee r i n9: Mm_/// RADS- BEW JDHq.-~, )-Y c. leo 1 ogy' DW rev 08/18/92 jo/6.011 Company /~C cC) . 10. 11. 12. 13 14 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... · 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ...................... Does operator have a bond in force ................................... Is a cc~servation order needed ....................................... .. 29. 30. 31. 32. Is administrative approval needed .................................... Is lease ntrnber appropriate .......................................... ~_ Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... .~ NO Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old well bore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~--OOm psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,,, Additional remarks' 33. m z Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history' file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 1 is type: LIS **** REEL HEADER **** MAC 92/11/12 AWS 01 **** TAPE HEADER **** MAC 11/12/92 LISTAPE 01 CO FIDEt TIAL Tape Subfile: 1 Minimum record length: Maximum record length: Tape Subfile 2 is type: LIS 2 records... 132 bytes 132 bytes **** FILE HEADER **** MAC .001 4096 CN WN FN COUN STAT : ARCO ALASKA INC. : P1-20 : POINT MCINTYRE : NORTH SLOPE : ALASKA HICi OFILHF, D OPEN HOLE DATA - 120' GAP IN THE DATA FROM 9615 TO 9735 MONOPOLE WAVEFORMS - 4 XMTR-RCVR PAIRS FOLLOWING IS A DEFINTION OF CURVES WAV0 = TlR1 WAVEFORMS WAVl = TlR2 WAVEFORMS WAV2 = TlR3 WAVEFORMS WAV3 = TlR4 WAVEFORMS TIME = START TIME FOR EACH XMTR-RCVR PAIR GAIN = GAIN CODE FOR EACH XMTR-RCVR PAIR GR = MAC GAMMA RAY RECEIVED DEC 1 1992 Alaska 011 & Gas Cons. Commission Anchorage FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units 1 DEPL LIS 68 1 F 2 WAV0 LIS 79 1 AMP 3 WAVl LIS 79 1 AMP 4 WAV2 LIS 79 1 AMP 5 WAV3 LIS 79 1 AMP 6 TIME LIS 79 1 USEC 7 GAIN LIS 79 1 EXP 8 GR LIS 68 1 GAPI *W denotes waveform curve API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 99 995 99 1000 62 995 99 1000 62 995 99 1000 62 995 99 1000 62 995 99 8 62 995 99 8 62 995 99 4 62 995 99 1 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 4024 RECEIVED DEC ~ 1 ~992 Alaska 011 & Gas Cons. Commission Anchorage * DATA RECORD (TYPE# 0) Total Data Records: 3089 4034 BYTES * Tape File Start Depth = 8958.000000 Tape File End Depth = 10502.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Rep Code: 79 Tape Subfile: 2 Minimum record length: Maximum record length: 9268 datums 18534 datums 3094 records... 62 bytes 4034 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MAC .002 4096 CN WN FN COUN STAT : ARCO ALASKA INC. : P1-20 : POINT MCINTYRE : NORTH SLOPE : ALASKA OPEN HOLE DATA - 120' GAP IN THE DATA FROM 9615 TO 9735 FOLLOWING IS A DEFINTION OF CURVES WAVO = TlR1 WAVEFORMS WAV1 = TlR2 WAVEFORMS WAV2 = TlR3 WAVEFORMS WAV3 = TlR4 WAVEFORMS TIME = START TIME FOR EACH XMTR-RCVR PAIR GAIN = GAIN CODE FOR EACH XMTR-RCVR PAIR GR = MAC GAMMA RAY * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units 1 DEPL LIS 68 1 F 2 WAV0 LIS 79 1 AMP 3 WAV1 LIS 79 1 AMP 4 WAV2 LIS 79 1 AMP 5 WAV3 LIS 79 1 AMP 6 TIME LIS 79 1 USEC 7 GAIN LIS 79 1 EXP 8 GR LIS 68 1 GAPI *W denotes waveform curve API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 99 995 99 1 1000 62 995 99 1 *W 1000 62 995 99 1 *W 1000 62 995 99 1 *W 1000 62 995 99 1 *W 8 62 995 99 1 *W 8 62 995 99 1 *W 4 62 995 99 1 4024 * DATA RECORD (TYPE# 0) 4034 BYTES * Total Data Records: 3089 Tape File Start Depth = 8958.000000 Tape File End Depth = 10502.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Rep Code: 79 Tape Subfile: 3 Minimum record length: Maximum record length: 9268 datums 18534 datums 3094 records... 62 bytes 4034 bytes Tape Subfile 4 is type: LIS **** FILE HEADER **** MAC .003 4096 CN WN FN COUN STAT : ARCO ALASKA INC. : P1-20 : POINT MCINTYRE : NORTH SLOPE : ALASKA CASED HOLE DATA - USED TO FILL IN THE GAP FROM 9615 TO 9735 MONOPOLE WAVEFORMS - 8 XMTR-RCVR PAIRS FOLLOWING IS A DEFINTION OF CURVES WAV0 = TlR1 WAVEFORMS ; WAVl = TlR2 WAVEFORMS WAV2 = TlR3 WAVEFORMS ; WAV3 = TlR4 WAVEFORMS WAV4 = TlR5 WAVEFORMS ; WAV5 = TlR6 WAVEFORMS WAV6 = TlR7 WAVEFORMS ; WAV7 = TlR8 WAVEFORMS TIME = START TIME FOR EACH XMTR-RCVR PAIR GAIN = GAIN CODE FOR EACH XMTR-RCVR PAIR GR = MAC GAMMA RAY * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units 1 DEPL LIS 68 1 F 2 WAV0 LIS 79 1 AMP 3 WAV1 LIS 79 1 AMP 4 WAV2 LIS 79 1 AMP 5 WAV3 LIS 79 1 AMP 6 WAV4 LIS 79 1 AMP 7 WAV5 LIS 79 1 AMP 8 WAV6 LIS 79 1 AMP 9 WAV7 LIS 79 1 AMP 10 TIME LIS 79 1 USEC 11 GAIN LIS 79 1 EXP 12 GR LIS 68 1 GAPI *W denotes waveform curve API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 2 2 2 2 2 2 2 2 2 2 4 4 99 995 99 500 62 995 99 500 62 995 99 500 62 995 99 500 62 995 99 500 62 995 99 500 62 995 99 500 62 995 99 500 62 995 99 16 62 995 99 16 62 995 99 4 62 995 99 1 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 4040 * DATA RECORD (TYPE# 0) 4050 BYTES * Total Data Records: 3089 Tape File Start Depth = 8958.000000 Tape File End Depth = 10502.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Rep Code: 79 Tape Subfile: 4 Minimum record length: Maximum record length: 18536 datums 49424 datums 3094 records... 62 bytes 4050 bytes Tape Subfile 5 is type: LIS **** FILE HEADER **** MAC .004 6144 CN WN FN COUN STAT : ARCO ALASKA INC. : P1-20 : POINT MCINTYRE : NORTH SLOPE : ALASKA CASED HOLE DATA - USED TO FILL IN THE GAP FROM 9615 TO 9735 DIPOLE WAVEFORMS - 8 XMTR-RCVR PAIRS FOLLOWING IS A DEFINTION OF CURVES WAV0 = TlR1 WAVEFORMS ; WAV1 = TlR2 WAVEFORMS WAV2 = TlR3 WAVEFORMS ; WAV3 = TlR4 WAVEFORMS WAV4 = TlR5 WAVEFORMS ; WAV5 = TlR6 WAVEFORMS WAV6 = TlR7 WAVEFORMS ; WAV7 = TlR8 WAVEFORMS TIME = START TIME FOR EACH XMTR-RCVR PAIR GAIN = GAIN CODE FOR EACH XMTR-RCVR PAIR GR = MAC GAMMA RAY * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units 1 DEPL LIS 68 1 F 2 WAVO LIS 79 1 AMP 3 WAVl LIS 79 1 AMP 4 WAV2 LIS 79 1 AMP 5 WAV3 LIS 79 1 AMP 6 WAV4 LIS 79 1 AMP 7 WAV5 LIS 79 1 AMP 8 WAV6 LIS 79 1 AMP 9 WAV7 LIS 79 1 AMP 10 TIME LIS 79 1 USEC 11 GAIN LIS 79 1 EXP 12 GR LIS 68 1 GAPI *W denotes waveform curve API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 99 995 99 720 62 995 99 720 62 995 99 720 62 995 99 720 62 995 99 720 62 995 99 720 62 995 99 720 62 995 99 720 62 995 99 16 62 995 99 16 62 995 99 4 62 995 99 1 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 *W 1 5800 * DATA RECORD (TYPE# 0) 5810 BYTES * Total Data Records: 3089 Tape File Start Depth = 8958.000000 Tape File End Depth = 10502.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Rep Code: 79 Tape Subfile: 5 Minimum record length: Maximum record length: 18536 datums 49424 datums 3094 records... 62 bytes 5810 bytes Tape Subfile 6 is type: LIS **** TAPE TRAILER **** MAC 11/12/92 LISTAPE O1 END OF THE TAPE **** REEL TRAILER **** MAC 92/11/12 AWS 01 END OF THIS REEL Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 12 NOV 92 11:32a Elapsed execution time = 3 minutes, 34.8 seconds. SYSTEM RETURN CODE = 0 'CO FIDEN11AL * AbASKA COMPUTING CENTER * * , ****************************** *---'-'' $CHI~U~BERGMR ******************************* CO~PAMY NAME : ARCO AbASKA, INC, WELb NAME : PI-20 FIEbD HAME : POINT MCiINTYRE BOROUGH : NORTH SLOPE API., NUMBER I 50-029-22288 REFEREN E NO : 92713 DEC ~) 1 1992 Alaska 0ii & 6~m Cons. 0ommisslon AnchOrage ,IS Tape Verification Listing ,chlumberger Alaska Computing Center **** REEL HEADFR SERVICE NAME : DPC2 DATE : 12/09/92 ORIGIN : ADV R~EL NA~E : TAPE1 CONTINUATION # PREVIOUS REEL CO~EMT : ANADRILL LIS Tape **** TAPE HEADER SERVICE NAME : DPC2 DATE : 12/09/92 ORIGIN : ADV T~PE NAME CONTINUATION # : PREVIOUS TAPE COMMENT : Anadril! LIS tape 9-DEC-1992 09:05 PAGEI **** FILE HEADER **** FILE NAME : ADV .001 S~RVICE : DPC VERSION : ~,0 DATE : 12/09/92 MAX REC SIZE : 10~4 FILE TYPE : LO LAST FILE : , ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** · · TYPE R~.P.,. CODE VALUE I 66 0 2 66 0 3 73 108 4 66 255 5 66 6 73 0 7 65 FEET 8 68 1, 9 65 FEET 11 66 9 12 68 13 66 0 4 65 FEET 5 66 68 16 66 ! 0 66 0 RECEIVED DEC 5 1 1992 Alaska Oil & ~as Cons. Commission Anchorage IS Tame Verification Llstin~ cblumberger AlasKa Computing Center 9-DEC-1992 09:05 PAGE.' · ~ SET TYPE - CHAN *~ ......--.....,,,,-,--...-..--... ...... .......-. ....... ....,,,,......................... N~M~ $~RV ERVICE APIAPIAPI AP! FILE NUMB SIZE REPRPHOCES$ ID ORDER ~ LOG TYPE CLASS MOD NUmB SA~P E.LE~ CODE (HEX) DEPT DPC FEET 0000000 O0 000 O0 0 0 ! I 4 68 TVD DPC FEET 0000000 O0 000 O0 0 0 ! ! 4 68 TI~E DPC SEC 0000000 O0 000 O0 0 0 ! ! 4 68 DATE DPC 0000000 O0 000 O0 0 0 1 ! 4 68 ~Op DPC FPH 0000000 O0 000 O0 0 0 ! ! 4 68 ROp5 DPC FPH 0000000 O0 000 O0 0 0 1 ! 4 68 TOTH DPC MRS 0000000 O0 000 O0 0 0 ! 1 4 68 SwoB DPC KLBS 0000000 O0 000 O0 0 0 1 1 4 68 STO~ DPC UNKN 0000000 O0 000 O0 0 0 ~ ! 4 6~ RPM DPC RPM 0000000 O0 000 O0 0 0 I ~ 4 68 SPPR DPC PSI 0000000 O0 000 O0 0 0 1 ! 4 6~ GTF DPC DEG 0000000 O0 000 O0 0 0 I I 4 69 ~TF DPC DEG 0000000 O0 000 O0 0 0 1 ! 4 68 DWOB ~PC KLBS 0000000 O0 000 O0 0 0 1 ! 4 68 DTO~ DPC UNKN 0000000 O0 000 O0 0 0 1 1 4 68 FRIC DPC PCT 0000000 O0 000 O0 0 0 1 I 4 68 DRA~ DPC PCT 0000000 O0 000 O0 0 0 1 1 4 6~ TD DPC 0000000 O0 000 O0 0 0 I 1 4 68 SORD DPC 0000000 O0 000 O0 0 0 ! 1 4 68 ED DPC 0000000 O0 000 O0 0 0 1 I 4 68 EDN DPC 0000000 O0 000 O0 0 0 1 1 4 6~ FOR$ DPC KPSI 0000000 O0 000 O0 0 0 I I 4 68 FOR~ OPC 0000000 O0 000 O0 0 0 1 1 4 66 XSTO DPC UNKN 0000000 O0 000 O0 0 0 1 I 4 6~ FLAT DPC 0000000 O0 000 O0 0 0 I I 4 68 G~ DPC CPS 0000000 O0 000 O0 0 0 1 1 4 68 G~C DPC CPS 0000000 O0 00o O0 o 0 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000o00000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 o000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DEPT DPC 3501.000 TVD,DPC 3590.509 TIME.DPC 76698 ROP:DPC 188,100 ROP5.DPC 579.800 TOTH,DPC STO~..DPC . 2~7i0 RPM,DPC 59.550 SPPR.DPC .-48 MTF.,DPC .999,250 DWOB,DPC -999.250 DTOR,DPC 999 D~AO,DPC -999~250 TD,DPC -99~,250 SQRD.DPC -999 ~DN,DPC -999,250 FORS, DPC -99 ,~50 FOR~ DPC -999 FLAT.DPC .-999.250 'GR,DP¢ -999.,~50 GR :DPt -999 DEPT.DPC 3600,000 TVD.DPC 3599 ' 99 '~00 TI~E.DPC '~OP.DPC 170.500 ROPS,DPC 377. TOT. H.OPC STOR'DPC 0,000 RPM,DPC 0,530 SPPR.DPC MTF,DPC 3~4,800 DWOB~DPC 10.750 DTOR.DPC DHA~.DPC; 100'000 TD.DPC 0.114 SQRD,DPC ~D~.DPC 0,816 rOPS,DDC 0.470 FOR~.DPC FLAT,DPC o,231. G~,DPC -999,~50 GRC,DPC DA~E SWOB 000 GTF ~50 FRIC 25O ED .250 XSTO ~50 DPC DPC DPC DPC DPC DPC 70 S~OB2DPC 2401 000 GTF DPC -0 ]40 FHIC!DPC 0 ~'32 ED DPC -0156 XSTO.DPC -999 250 I0119~ 000 860 -999 0 -999 0 ,,o -59,300 -9992~50 0,399 0,000 I8 Tape Verification bisting chlumberger AlasKa Computing Center DEPT DPC 3700.000 ~OP~DPC lo05,500 STO~.DPC 0,000 ~TF.DPC 38.000 D~AC.DPC -999.250 EDN.DPC -999.250 FLAT.DPC -999,250 DFPT DPC 3800.000 ROP'OPC 351.700 STOR]DPC 7.490 MTF.DPC 131 500 DRAG.DPC -999~250 EDN.DPC -9q9 250 FLAT,DPC s o .o c o.ooo TF: PC 306.400 O"A PC '999'250 EDN.DPC '999.250 FbAT,DPC -999.250 DEPT.DPC 4000 000 Rop.upc 8TOR.DPC 0.000 )TF,DPC 316.000 DR~G.DPC 22 '~0 FLAT.DPC 0.231 DEPT.DPC ~OP DPC STO~DPC ~TF DPC DRAG DPC EDN DPC FLAT DPC D~PT DPC ROP DPC STO~ DPC ~T? DPC D~AG DPC gDN DPC FLAT,DPC DEPT.DPC ROP'OPC STOR,DPC ~T~,DPC D~A~"DPC EDN'DPC FLAT,DPC 4100.000 i00.100 0 000 345 200 -999 250 -999 250 '999,~50 42o0,000 I69'500 0,000 3452700 4'290 -9992~250 0,784 4300.000 75,600 4.040 90 400 2 , g,880 O92 ~'784 TVD.DPC ROPS.PPC RPM.DPC DwOB.DPC TD.DPC FOR$.DPC GR.DPC TVD.DPC ROP5.DPC RPM.DPC DWOB.DPC TD.DPC FOR$..DPC GR.DPC TV~DPC ROP ~DPC RPM*DPC DWOB,DPC TD.2DPC FOR$.DPC ~.DPC TVD,DPC ROPS.DPC RP~DPC DWOB]DPC TP.DPC FOR$,DPC GR.DPC TVD.DPC ROPS.DPC RPM,DPC DWOB.,DPC TD.DPC FORS, DPC GR.DPC TVO,DPC ROPS.,DPC RPM,DPC DWOB,DPC TD,DPC FORS,DPC GR.DPC ?VD'DPC ROPS.DPC RP~.DPC DWOB.DPC TD.DPC FOR$..DPC GR,DPC 9-DEC-1.99~ 00:05 3698.967 TI~E.OPC 344,700 TOTH,DPC 0.250 SPPR.DPC -999.250 DTOR.DPC -999.250 SORD,DPC -g99'250 FOR~.OPC -999.250 GRC.DPC 3798 470 TI~E,DPC 81 130 SPPR,DPC -999.250 DTOR OPC 0.041 SORDiDPC 4 ]90 FOR~ opc -999:250 GRC.DPC 3897.468 TIME.DPC 97 500 TOT. DPC 02770 SPPR2OPC - 99.250 DTOR.DOC '~99'250 SQRO.DPC -999,250 FOR~,DPC -999,250 GRC.DPC 3996.226 TINE.DPC !83'700 TOTH,DPC 0.740 SPPR,DPC 27 800 DTOR,DPC 0 054 SORD,DPC 1.600 FORM.DPC -999.250 GRC.DPC 409.4, ME DPC . 0'd6~ TOTH'DPC SPPR,DPC .999.~ DTOR'DP.C 999, SORD*DPC :999' FORM,DPC 999j~g GRC'DPC 4191,303 TIME.DPC ~31.200 TOT~,DPC 0'970 $PPR,DPC 35'800 DTOR,DPC 0'049 $ORD.DPC B~040 FOR~,DPC -999,250 G. RC,DPC 1286.955 TIME.DPC t32~800 TOTH,DPC 20'200 32.800 DTOR,DPC O'OS7 SOlD DPC 7,290 FOR~ DPC 999.250 GRC DPC 341.433 1 470 23!5 000 -999 250 -999 250 -999 250 -999 250 2046 583 1 810 2529 000 -999 250 0 165 7 181 ss49ii°° 2514 O0 999.250 999.250 -999.~50 -999.250 9355.299 3.~370 455'000 1.520 0.202 -9991250 12777' ~750 4 150 ~572000 999 250 -999 25O -999 250 -999 25O ~74.699 4,710 2642.000 1'780 0,146 -999,.250 2471'0~0 o -999 50 OATE.DPC SWOB.DPC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB.DPC GTF.DPC FRIC.DPC ED,DPC XSTO,DPC DATE.DPC SWOB.DPC GTF..DPC FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB.DPC GTF,DPC FRIEg. DPC .DPC XSTO.DPC DATE,DPC SWOB,DPC GTF,DPC FRIC,DPC ED,DPC XSTO.DPC DATE,DPC SWOB.DPC GTF,DPC FRIC,DPC ED,DPC XSTO~DPC D tg,'O.C SWOB.DPC GTF,DPC FRIC.DPC ED.DPC XSTQ.DPC PAGE: 1.01292.000 25.830 25.000 -999.250 =999'250 -999.250 101292 000 000 -999 250 -99925O 0 000 IO1292.000 37.460 '44,300 -999'250 -999,250 -999,250 0'600 101292'000 43 ~30 :'i'~' O0 -999'250 -999 50 10i2'92'0'00 ~1.'880 . ,8,500 999'250 '0'055 0,000 i01292'000 '14'970 65".200 '999'250 0,031 0'00o ,IS TaPe Verification Listing ,chlumberqer AlasKa Computing Center DEPT DPC 4400.000 TVD.DPC '~OP:OP¢ 377.700 RUPS.DPC $TO~.DPC 9 790 RPM.DPC ~Tr. DPC -999~250 DwOB.DPC D~AG,DPC -999,250 TD.DPC EDN,DPC -999,250 FO~$,OPC F~AT,DPC -9q~,250 GR.DPC DKPT DPC 4500,~00 TVD,DPC ~OP:DPC 61,~00 ROPS,DPC 5TO~,~PC 0,000 RPM,DPC MTF,DPC 293.B0o DWOB.DPC D~AG,DPC -999,250 ED~*BPC -0.124 FOR .DPC FLAT.DPC 1.465 GR.DPC p~P? ~Pc 46oo.ooo Tvo ~pc D.AG,OPC -999.250 TO.OPC EDN.DPC -999,250 FOR$.DPC FLAT.DPC -999.250 GR.DPC DMPT.DPC 4700,000 TVD..DPC ROP.DPC 142,500 ROP5"DPC STO~,DPC 7.790 RPM,DPC MTF.DPC 353,200 DWOB,DPC DRAG'DPC :999'250 TD,DPC ~DN'DPC 999.250 FORS-DPC FLAT.DPC -999.250 GR,D~C DEPT DPC 4800,000 TVD'DPC ROP.:DPC 76'700 ROP5.DPC STO~.DPC 0'000 RPM,DPC MTF,DPC 241,800 DWOB.DPC DR~GiDPC 22,990 TD,DPC EDN'DPC 0,4~5 FOR$,DPC FLAT'DPC 3,055 GR,DPC ~OP.DPC ' 3 00 ROP5.DPC STOR.DPC 0.620 RPM.OPC "TF.DPC .325,700 DWOB,DPC DRAG DPC 999,250 TD.DPC EDN:DPC 0.378 FORS.DPC FbA?,DPC 3'~6 GR'DPC ooo.ooo ~OP.DPC 88.100. ROp5 PC STOR DPC 6,460 RPM.DPC MTF:DPC !68,700 DwOB.DPC D~AG,DPC -999,250 TD'DPC MDN.DPC -999.250 ~ORS..DPC 9-DEC-19g~ 09:05 4381 121 514~000 118 140 -999:250 -999.250 -999.~50 -999.250 44~$.070 .400 0.590 -999,250 O~ -999.250 I . O0 0 40O '9991250 -999 250 -999 250 '999.250 465 1 4,940 -999,~50 -999.~50 4742,6~7 77.9.0 .540 3.680 0'081 -999.~50 4829.4!~ 7~,10 .790 35,930 1~'078 ,470 -999,~50 14.035 4978.600 71,060 -999.250 -999,250 -999,~50 TIME.DPC TOTH.DPC SPPR.DPC DTOR.DPC $ORD.DPC FORM.DPC GRC.DPC TIME,DPC TOTH,DPC SPPR.DPC DTOR.DPC SQRD.DPC FORM,DPC GRC,DPC TIME,DPC TOTS,DPC SPPR.DPC DTOR.DPC $ORD,DPC FOR~.DPC ~RC,DPC TIME DPC TOTH~DPC SPP~.DPC DTOR,DPC $QRD,DPC FORM,DPC GRC,DPC TINE,DPC TOTH~DPC SPPR,DPC DTOR,DPC SORD'DPC FORM,DPC GRC~UPC TIME,DPC TOTH,DPC SPPR,DPC DTOR,DPC SORD,DPC FOR~'DPC GRC,DPC TIME,DPC TOTM,DPC SPPR.DPC DTOR,DPC SQRD.DPC FORM.DPC 3,898 18955,40o 2577.o00 -999.~50 -999.250 -999.250 -999.250 4 715 24216~490 2582o000 -999.250 0,112 -0,941 -999.250 . 50 2564 000 -9 9::so -999'250 -999..250 -999.250 34446.164 8,400 ~527,:000 .999.250 .999,250 .999.250 999,~50 38967,000 9.290 .000 270~,540 0'10I 0.130 -999.250 44873'617 i~!,0.,550 2574-!000 :2.870 0.097 . 0'232 999'250 ! 4O - 99 50 ~999 ~50 -999:' 50 DATE.DPC SWOB.DPC F~IC PC ED.DPC XSTO.DPC DATE DPC SWOB~DPC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB'DPC ~TF,DPC FRiC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB.:DPC GTF,OPC FRIC.DPC ED'DPC XSTQ.DPC DATE'DPC SWOB.DPC GTF,DPC FRIC'DPC ED.,DPC XSTO,DPC DATE.DPC SWOB,DPC GTF'DP FRIC,D~ ED DPC XSTO:DPC DATE DPC SWOB:DPC GTF.DPC FRIC,DPC ED.DPC XST~.Dpc PAGE: 101292,000 30.820 -999.250 -999..250 -999.250 -999.250 101292 00 49:~90 6.½00 -999. 50 0 o:Aoo 4 110 3 :~00 99 50 999,250 101292'000 45.540 '7.,700 999'250 999.250 999.250 · O0 5,800 0'412 0,000 92;,000 10i24 0 9'2~0 0'394 0200o o12v2'Ooo .36'970 "53'600 '999,250 '999,250 '999,250 Tame Verification ListinO chlumberger Alaska Computing Center FLAT.DPC D~PT,DPC ~OP.DPC STO~.DPC ,TF.DPC D~AG.DPC EDN.DDC FI, AT.DPC DEPT.DPC ROP,DPC STO~'DPC ~TF.DPC DRAG,DPC EDN.DPC FbAT,DPC DEPT.DPC ~OP.DPC sTo~'DPC MTF,DpC D~AC.DPC ~DN.DPC FLAT,DPC DEPT*DPC ~OP~DPC STOR'DPC NTF'DPC DRAG.DPC EDN.DPC FLAT'DPC DEPT*DPC ~OP,DPC STOR.,DPC MTF'DPC EDN.DPC FLAT.DPC DEPT DPC ~OP DPC STO~ DPC ~TF DPC DRA~ OPC EDN.DPC FLAT,DPC DEPT,DPC .~O'P.DPC ~TF;DPC DRAG,DPC -999. 5o G .n.c 5~00.000 TVD.DPC 4 o.5oo 6.380 RPM:DPC 143.200 DWOB.DPC '999.250 FOR~:DDC 5~00.000 TYD.~PC 83.900 ROPS,DPC 0,000 RPM.DPC 180.800 DwOB.DPC -999.250 TD.DPC -999.250 FOR$.DPC -999,250 GR.DPC 5300.000 TYD,DPC 24.600 ROP5.DPC 0'000 RP~.DPC 324.800 DWOB.DPC 27,500 T~,DPC -0.174 FORS.DPC ],481 GR,DPC 5400.000 TVD,DPC ]76.200 ROPS,DPC 7,760 RPM,DPC 141 ~00 DWOB.DPC - 50 TD.~PC '999 50 FOR$,DPC -999:50 5500,000 TVD,DPC 264 ~00 ROPS'DPC 5:O0 RP~.DPC 250.500 DWOB~DPC -999.250 TD.DPC -999,250 FOR$.DPC -999,250 GR.DPC 5600,000 TYD.DPC 2~0,000 ROPS'DPC 1~,600 RPM.DPC 186.300 DWOB.DPC -999,250 TD.DPC 7oo.ooo 9-DEC-1992 09:05 -999. 4998. 403. 74. -999 -999. -999. -999. 5081. O, -999, -999° -999. -999. 5163. 32. O. 52. O, 31. -999. 5244, 377~ -999, -999' :999, 999, 5326, 87. 97' -999, 5406, 148' 85° 2999, 999, ~999, -999, 5487, 90 27 ~999 250 GRC.DPC 410 TIME.DPC 800 TOTH,DPC 990 SPP~,DPC 250 DTOR.DDC 250 SORD.DPC 250 FOR~.D~C 250 GRC.DPC 593 TIME.DPC 600 TOTH,DPC 810 SPPR.DPC 250 DTOR,DPC 250 SQRD,DPC 50 FOR~ DPC 5o c c:opc ~2 TIME,DPC 0 TOTH,DPC 570 SPPR.DPC 3~0 DTOR,DPC 6 SORD.DPC 20 FOR~,DPC 250 GRC.DPC ~ TI~E,DPC ~ ~ TOTH.DPC 900 8PPR,:DPC ~0 DTOR.DPC 0 SORD,DPC 250 FOR~,DPC 250 GRC,DPC ~00 TOTH,DPC 4so 0 SORO.DPC 50 FOR~ UPC 690 TIM~,DPC 000 TOTH,DPC 430 SPPR,,DPC 250 ~TOR,DPC 250 oORD'DPC 250 FORH.DPC 250 GRC,DPC 2!6 TI~E.DPC 200 TQTH,DPC 900 SPPR,DPC 680 DTOR,DPC 250 $ORD,DPC -999.950 52488.648 12.140 2628.000 =999 250 -999o250 -999.~50 -999.250 55574.56] 12.740 2620.000 :999.250 999.250 -999.~50 -999.'250 62295,!02 !4,200 2776.000 -0739 -999:250 81980,533 14,870 ~90!,000 ,999..250 ,999'250 ~999.250 999'1250 84305,219 15':420 ~762'000 =999,250 .999,250 999.250 -999..250 750 750 15 930 2951 000 -999 250 -999 ~50 -999.250 -999,.250 .430 012,000 3999,~50 -999'250 DATE.DPC SWOB.DPC GTF.DPC F~IC.DPC ED.DPC XSTO,DPC DATE.DPC SWOB:~PC GTF PC FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB.DPC GTF,DPC FRIC.DPC ED.DPC XSTO,DPC DATE,DPC SWOB*DPC GTF,DPC FRIC,DP ED*DP~ XSTO~DPC DATE,DPC SWOB.DPC GTF'DPC FRIC,DPC XSTO.DPC DATE'DPC SWOB,DPC GTF,DPC FRIC.DPC ED,DPC XSTO.DPC DATE.DPC SWOB.DPC GTF, DPC FRIC. DPC ED ,DPt PAGE{ 101292 000 21 700 97 600 -999 250 -999 250 -999 250 101292,000 ,670 -999.250 -999.250 -999.250 101!92'000 ~4,670 99~'~000 ,250 0,215 o;:ooo 101292,000 3~,200 -99 '250 '999,250 !o1291.OOo -.9 ,250 '9~9.,250 '~99'250 - 9,2:50 10!392,:000 5 *320 99~'250 -999,250 '999,250 '999"250 10~392,000 5 !, :,~, 920 53,90 0 999,250 '999.250 Tape Verification bistlng chlumberger Alaska Computing Center EDN.DPC -999.25n FO~S.DPC FLAT.DPC -999.250 GR.DPC EDN.DPC -999.250 FOR$.DPC FLAT.DPC -999,250 GR.DPC DEPT.DPC 5900.000 TVD.DPC ROP.DPC 172.300 ROP5.DPC STOR.DPC 11.150 RPM.DPC MT~.DPc 79.500 DWOB.DPC DRAG.DPC 2.880 TD DPC EDH.DPC 0.749 FOR$:DPC FLAT.DPC 3.814 GR.DPC STOR.DPC 10.300 RPM.DPC MTF.:DPC t06.500 DWOB.DPC DRAG.DPC. -999'250 TD.DPC EDN.DPC -999.250 FORS.DPC FLAT.DPC -999.250 GR.DPC DEPT DPC ROP:DPC STOR.DPC ~TF,DPC DRAG.DPC EDN.DPC FLAT,DPC 6100 ~0 121 -999, 0, 5' 000 TVD.DPC :300 ROP5*DPC 070 RP~'DPC 300 DWOB.DPC 250 TD.DPC 266 FORS.DPC 016 GR.DPC DEPT.DPC 6200.000 TVD,DPC ROP.DPC 54,400 ROPS,DPC STO~*DPC 10,660 RPM.DPC MTW.DPC 196,100 DWOB.DPC D~G,DPC -999'~50 TD.DPC ~D~'DPC -999.z50 FOR$.DPC FLAT~DPC -999.250 GR.DPC DEPT ~OP ~TF DRAG FLAT DPC DPC DPC DPC DPC DPC 6300, i07. 12. 175. -999. -999. -999. 000 TVD,DPC 900 ROP5.DPC 780 RPM.DPC 500 DWOB.DPC 250 TD.DPC 250 FORS,DPC 250 GR.DPC D~PT. ROP, STO~ ~T~' DPC DPC DPC DPC 6400. .{79. !!. 160. 9-DEC-1992 09:05 -999.250 -q99.250 5567,798 169.900 87.590 -999.250 999.250 -999.250 564~i294 12 500 83 480 5!,680 3 -999.~50 5728 744 123 700 83 70O -999 50 -999 ~50 -999 250 -999 250 5809 3 : oo 25,200 '999,2:50 0.076' !14,350 -999.250 5889.449 67.'I00 69,190 '999..~50 -9 ,~50 -999.~50 6.300 67,920 -999~250 -999,250 -999"250 FORM.DPC G~C,DPC TIME.DPC TOTH.DPC SPPR.DPC DTOR.DPC SORD.DPC FOR~.D~C GRC.DPC TI~E.DPC TOTH,DPC SPPR,D~C DTOR,DPC $ORD DPC FORM.:DPC GRC.DPC TIME,DPC TOTH,DPC SPPR.DPC DTOR,DPC ~ORD,DPC FOR~.DPC GRC,DPC T]~E,DPC TOT~,DPC SPPR,DPC DTO~,DPC SQRD*'DPC~ FORM,DP~ GRC*DPC :TIM~,.DPC TOTH,OPC SPPR*DPC DTOR'DPC $ORD'DPC FOR~,DPC GRC,DPC TI'~E.DPC TOTH,DPC 8PPR,DPC DTOR.DPC SORD,DPC FOR~,DPC GRC,DPC TI'~E,DPC TOTH,DPC SPPR.DPC DTOR.DPC 999.250 6273.149 17.130 ~966.000 999.250 : 99. so 999.250 -999.250 99~0.666 18.030 2963.000 6.510 0.113 0.226 -999.250 ~6656.949 9..330 7 .ooo -999'250 -999'250 -999,250 -999.~50 '280 747.000 2999.250 . 0'039 '990'107 9.~250 °lg 2767 00 -9991 50 -999I 50 -999 50 29473.199 040 000 29991'25O 999.~50 -999.250 31869'598 22,.400 .~99'250 XSTQ.DPC DATE DPC SWOB~DPC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB.DPC GTF DPC FRIC:DPC ED.DPC XSTO.DPC DA?E.DPC SWOB,DPC GTF,DPC FRIC.DPC ED*DPC XSTO.DPC ~ATE DPC SWOBiDPC GTF DPC FRIC DPC EDDP¢ XST'Q:DPC DATE.DPC SWOB.DPC ~TF.DPC FR!C.*DPC ED.DPC XST~,DPC DA~E,DPC SWOB,DPC GTF,DPC FRIC,DPC ED,DPC XSTO.DPC DATE,DPC SWOB,DPC GTF.DPC FRIC*DPC PAGE{ '999.250 101392,000 41,890 '1~4,400 '9 .250 -999250 -999:250 4 570 11:I°°,o OO 101392.000 60'340 -45'.400 -999,250 :999.260 999'250 lo:i392.ooo 47'4i0 *999, 101392:*000 .46,570 :999,260 1999,260 9'99'.250 101392.000 55'000 -43'300 '999,250 '999~=250 '999.'250 10139:!"0004~,660 !:25~ 400 '999,250 .IS Tape ·Verification I,istinq .cblumberger AlasKa Computlng Center D~Ac, DPC -999,250 TD,DPC F..D'~:DPC -999,250 FORk DPC FLAT' DPC -999,25() GR;DPC D~PT.DPC 6500.000 TVD.DPC ROP.DPC 55.400 ROPS.DPC STO~.DPC 13.560 RPM.DPC ffTF.OPC 174.000 DWOB.DPC D~AG.DPC -999.250 TD.DPC ~DN.DPC O.9X] FORS.DPC FLAT.DPC 0.637 GR.DPC D~PT.DPC 6600.000 TVD.DPC . OP.DPC 98.600 ROP5.DPC STOR.DPC 16.330 RPM.DPC ~TF.DPC 97,500 DWOB.DPC DRA~*DPC -999.250 TD.DPc EDN.DPC -999 ~50 FOR$.DPC FLAT.DPC -999:250 GR.DPC DEPT DPC 6700 000 TVQ.DPC oPl PC ] ]14oo STO~.DPC 10.8~0 RP~..DPC ~TF.DPC 206.600 DWOB.D~C D~AG.DPC -999.~50 TD~DPC ~DN.DPC -999 ~50 FOR$.DPC FLAT;DPC -999:250 GR,DPC DEPT DPC ~OP DPC STORDPC ~'TFDPC DRAGDPC ~DN'DPC FLAT.DPC 6800.000 TVD.DPC 294,800 ROP5.DPC 11,570 RP~,DPC 95'700 DwOB.D~C -999,~50 TD.DPC -999':2'50 FORS'DPC -999,~50 GRoDPC DEPT.D~C gOP.DPC STOR,DPC ~TF.DPC D~A~'DPC EDN,DPC FLAT.DPC 9-DEC-1992 09:05 -999.250 -999.250 -999'250 6131.38! 538O0 83:040 51.820 0.126 .47.430 -999.250 6212.669 107 000 87:450 -99 250 -99 0 6~94. 76,4900 -999,~50 -999. 50 -999,~50 -999' 50 6375 693 266 200 77 880 -999 250 -999 250 -9'99 250 -999 6900,000 TVD,DPC 6456,611 221,000' ROPS,DPC 70'800 14,380 RP~.DPC i 76,020 312,500 DWOB,DPC 999'250 -999.250 TD.DPC ~99,R50 -999..~50 FOR~,DPC 9991~50 -999.250 GR,DPC 999.~50 D~PT.DPC 7000,000 TVD.DPC ROP'DPC 30.200 ROPS*DPC STOR.DPC ~.1',290 RP~*DPC ~T~,QpC 160.200 DWOB.DPC DRAGoDPC -999,250 TD,DPC ~DN.DPC !,~07 'FORS,DPC FLAT.DPC 0,:177 GR'QPC 37 3 70 0 37:~ 7 2O 0,133 87.260 -9991250 $ORD.DPC FOR~.DPC TI~.DPC TOTH,DPC SPPR.DPC DTO~.D~C SQRD.~PC FOR~.D~C G~C.DPC TI~E.DPC TOTH,DPC SPPR.DPC' DTOR.DPC 5QRD,DPC FORM.~DPC GRC.DPC TIME.DPC TOTH,DPC SPPR.DPC SQR DPC FORM,DPC GRC,DPC TIME,DPC TOTH.,DPC SPP'R,DPC DTOR*DPC $QRD,DPC' FORM*DPC GRC'DPC TIME.DPC~ TOTH,D~C SPPR,DPC DTOR.DPC ~O~D,DPC FOR~,DPC GRC.DPC: TI~E,'DPC TOTHiDPC: SPPR.DPC DTOR,DPC SQRD.DPC FoRM.DPC GRC'QPC 999.250 999.250 999.250 72479.281 0.500 3066.000 ~:990 O8O ;g:oo - . 250 76455.750 ! 480 31941000 999.~50 -999.~50 -999.250 ~3930.28! 0,800 3304..000 -999.250 -999.250 -999.~50 -999.~50 27320,454 !.480 32 4,0 0 '9~ 0 9.2 0 -999',~0 -999~250 33423'016 2.640 ~172,'000 999,250 2999°.250 .999.~50 999..~50 39813:,i95 3.750 3146'000 5,020 0.05! 0.000 -999.~50 ED.DPC XSTQ.OPC DATE.DPC SWOB.DPC GTF.DPC FRIC.DPC ED.DPC XSTQ.DPC DATE.DPC SWOB.DPC ~TF.DPC FRIC.DPC ED.DPC XST~.DPC D~TE.DPC SWOB.DPC ~TF.DPC FRIC.DPC ED.DPC X$?O'DP¢ DATE.DPC 8WOBiDPC GTF,DPC FRIC,.DPC ED.DPC XSTQ.DPC DATE.DPC SWOB.DPC GTF.DPC FRIC,DPC ED,.DPC XSTO'DPC DATE,DPC SWO~,DPC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC PAGEI -999,250 -999.250 101392,000 55,680 .-42,500 0 0 44'914 O. 0,000 5O5 ! oo -999 50 -999 50 -999,250 t01492,000 . 31',030 ,999,250 ;999.250 999'250 -999.250 I01492~000 -35.o2o - .29,700 ;999' 250 ~999,2'50 014m2'000 .2e.eoo .. 43,800 · 250 '"999,250 O1492,000 35,930 -25,500 · 33,2 5 0 .1,10 t 0 ,.I60 IS Tape Verification Listing chlumberger AlasKa Computing Center DEPT.DPC 7100.000 ROP.DPC STO~.DPC 10.590 MTF.DPC 124.800 D~A~.DPC -999.250 EDN,DPC 1,064 FLAT.DPC 2,237 DEPT.DPC 7200.000 ROP.DPC 120.600 STOR.DPC 10.900 MTF..DPC 189.300 DRAG DPC 1.160 ~DNiOPC 1.000 FLAT DPC 2.801 DEPT.DPC 7300,000 ROP.DPC 28.200 STO~.DPC 11.210 ~TF,DPC 219.300 DRAG.DPC 1.850 EDN.DPC 0'72] FLAT.DPC ~,591 DEPT DPC R0P DPC STOA DPC ~TF DPC DRAG DPC EDN DPC FLAT'DPC DEPT.DPC ROP.DPC STOR'DPC ~TFiDPC D~AG.DPC ~D~,DPC FLAT'DPC D~PT.DPC ROP.DPC 8TOP.DPC ~TF'DPC D~AG.DPC MDN.DPC FLAT.DPC DMPT,DPC ~OP.DPC STOR2DPC MTF,DPC DRAG,DPC EDN,DPC FI~AToDPC 7400 000 54 800 !1 0go 215 000 -999 250 0.984 2.254 7500,000 56.000 t!.290 300.~00 1, 40 0.704 2.03! 7600.000 532200 {!.210 I50.000 2,720 0.618 3.065 7700.000 55.700 270,900 -999.250 -999,250 -999.250 TVD.DPC ~OP5.DPC RP~.DPC DWOB,DPC FOR DPC GR.DPC TVD.DPC ~OPS.DPC RPM.DPC DwOB,DPC TD.DPC FOR$.DPC GR.DPC TVD.DPC ROPS.DPC DWOB'DPC TD,DPC FOR$.DPC GR.DPC TVD.DPC ROP5.DPC RPM.DPC DWOB,DPC TD,DPC FOR$,DPC GR,DPC TVD.DPC ROP5*DPC RPM.DPC DwOB.DPC TD,DPC FOR$,DPC ~R,DPC TVQ.DPC ROP5 DPC RPM D~C DWOB'DPC TD'DPC FO~$,DPC GR,DPC TVD'DPC ROPS,DPC RP~.DPC DWOB.DPC TD'DPC FoRS~DPC GR.DPC 9-DEC-lgg2 09:05 6617.327 TIME.OPC 99.200 TOTH.DPC 74.400 SPPR, OPC 30.020 DTOR.DPC 0.144 SORD,DPC 11.720 FOR~.DPC -999.250 GRC.DPC 6697.515 TIME.DPC 141 ~oo To?. D~C 7o2o~o spP~:u~c 32 170 DTOR, DPC 0~ 41 8ORD. DPC 9 880 FOR~. DPC -999 ~50 GRC. DPC 6777.618 TIME.DPC 37 500 TOTH. DPC 36 7 0 DTOR,DPC 0 0 9 8QRD,DPC 57 860 FORM.DPC -999]250 GRC.~C 71'700 SPPR,OPC -~29,9 490 FO~,DPC 250 G~C,DPC 6937.466 TIME.DPC 59.800 TOTH* DPC 8{,920 SPPR'.DPC 42.480 DTOR.DPC 28,170 FOR~'DPC -999,250 GRC,DPC 70~7.342 TI~E,DPC 65.6OO T TO.,H. DPC 76. 780 SPPR,D~C 41'350 DTOR,DPC: 208. 099 8ORD.DPC .660 FOR{.DPC -999.,250 GRC'DPC 097. ~E,DPC 572213 4 TI 00 mOTH. DPC 75.~50 SPPR.DPC ,~99,250~ 99.~ 0 SORD.DPC -999,~0 FO~M,DPC -990'250 G~C'DPC 47086.633 5 75O ~o~52Ooo 4.4O0 o.102 0.343 -999.250 55007.398 7.530 3131.000 73O 0.350 -999.250 59897 297 8 610 3114 000 3 710 0 o52 0.047 -999.250 67980.094 10.450 3162,000 4~77o 0,080 . 0.265 999.250 76757281 12!~90 3178:000 4,700 0,082 .250 8]~09'453 14 0 4'190 0.076 0.001 -999'.250 3378'816 16.130 ~253,000 :999.~50 .999.250 .999.1250 -999'~50 DATE.DPC GT DPC FRIC.DPC ED.DPC xsTO.DPC DATE.DPC SWOB.DPC GTF.DPC F~IC.DP¢ ED.DPC XSTO.DPC DATE.DPC GTF.DP¢ FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWO~*DPC FRIC.DPC ED,DPC XSTO.DPC DATE.DPC SWOB*DPC GTF,DPC FRiC'DPC ED,DPC XSTO,DPC DATE.DPC SWOB.DPC GTF.DPC FRiC.DPC ED.DPC XSTO.DPC DATE.DPC GTFiDPC FRIC.DPC ED,DPC XSTO*DPC PAGEI 101492 000 28 53O -139 200 32 230 I 074 0 000 101492.000 35.230 2.500 31 0 0,000 101492,000 38,260 86,300 37.430 0 o ,600 A:g4° 4 0,000 1014921,000 44'800 1.7.600 33,080 0':757 0,ooo 101492'000 43,400 -8,500 32,980 0'676 o;ooo 101592,000 48,:!50 . 29,400 .999"250 999'250 -999,.~50 Tape Verification bistlmq chlUmberger lasKa Comput ng Center 9-DEC-1992 09:05 PAGE." DEPT,DPC 7800.000 ROD.DPC STO~.DPC 11.160 MTW.DPC 178,400 D~AG.OPC -999.250 ~DN.DPC -999.250 FLAT.DPC -999.250 D~p? DPC 790O.OOO "OP:DPC 40.2O0 STO~ DPC 10.7~0 MTF:DPC 155.900 o~p? uPc 8ooo ooo ROP.:DPC 44i800 S?Om. DPC it 610 ~TF,DPC i15 800 D~A~,DPC 7.740 EDN'DPC 0.539 FLAT.DPC 4.627 DEPT.DPC 81.00'000 ROP,DPC 43.800 STOR,DPC 12.060 MTF,DPC' 165.500 DRAG,DPC 3:~90 EDN,DPC 0 65 FLAT.DPC 4.524 DEPT DPC 8200 000 ROP:DPC 30:700 DRA~DP¢ 880 ~DN.DPC 0,353 FLAT,DPC 4.747 DEPT.DPC 8300. ROP.DPC 56, S~OD.DPC 12 TF.DPC ~42 DRAg'DPC -999 EDN.DPC -999 FLAT.DPC -999 000 600 320 800 250 .250 250 DEPT.DPC 8.400,000 ROP,DPC 42.800 STO,,DPC I2' 'MTF.,DPC !76.'~8 DRX~.DPC 5,660 ZDNiDPC 0.497 TVD.DPC ROP5.DPC Ro~.DPC DWOB.DPC TD.DPC FORS.DPC GR.DPC TVD DPC ROP5:DPC RP~.DPC D~OB.DPC TD.DPC FORS.DPC GR,DPC TVD.DPC ROP5.DPC RP~ DPC DwOBiDPC TD DPC FOR$ DPC GR.DPC TYD.DPC ROPS.DPC RP~.DPC DWOB,.DPC TD,DPC FORS,,DPC ~RiDPC TVD,DPC ROPS,DPC RPM,DPC DWOB*DPC TD'DPC ZORS;DPC GR*DPC TVD,DPC ROPS'DPC RPM:,DPC DWOB.DPC TD.DPC FO~S'DPC GR,DPC TVD'DPC ROP5.DPC RPM*DPC DWOB'DPC TD,DPC FOR$,DDC 7177.123 40.800 68 450 '9991250 '999.250 -990.250 -999.250 7257 019 4o: oo 64.110 44,730 0 106 34~510 -999.250 .600 87.540 48.980 ~0o -99g.250 8 50'600 0.099 42,880 '999.250 36 52,350 083 ~999,250 7575,025 51.700 84'3~0 ~999.~50 -999'250 -999,250 -999,250 765 4~.894 .'500 75 160 52 480 0 096 41 340 TIME.DPC TOTH,DPC SPPR.DDC DTOR.DPC $O~D.DPC FOR~.DPC GRC.DPC TIME,DPC TOTH.DPC SPPR.DPC DTOR,DPC SQRD,DPC WOR~.DPC GRC.D~C TIME D~C TOTH:DPC SPPR,DPC DTOR.DPC SQRD.DPC FORM.DPC GRC.DPC TOT~,DPC 8PPR.DPC DTOR,DPC $~RD.DPC FORM,DPC GRC,DPC SPPR.DPC DTOR'DPC SQRD*DPC FOR~'DPC GRC,DPC TiME,DPC TOTH,DPC SPPR,OPC DTOR,DPC SORD'DPC FORM*DPC GRC,DPC TIME.DPC TOTH,DPC SPPR,DPC DTOR,DPC SQRD,OPC FORM.DPC 11320.7!7 18.080 351000 999~250 999.250 -999.250 -999o~50 ~064] 480 20:450 3.000 3324,840 0 069 0~000 -999,250 38929.484 22.840 3385.000 4'840 0.068 . 0.000 999.~50 24.980 3~94,000 5'130 0.068 . 0,000 999.250 577~.,352 .,390 3454.000 4.460 0'054 -0'054 -999'250 65753'ii~0929:30 3407.000 - 99,250 - ~.250 3451,000 5-I20 ,.,066 ..000 DATE.DPC SwoB.DPC GTFDPC ED.DPC XSTO.DPC DA~zgPC SWOB PC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC DATE DPC GTF.DPC FRIC~DPC ED.DPC XSTO.DPC DATE'DPC SWOB.DPC GTFDPC FRIC DPC ED DPC XSTO DPC ATE.DPC WOB,DPC GTr'DPC FRiC'DPC ED'DPC XST~.DPC DATE,DPC SWO.B,DPC GTF.,DPC FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB.DPC GTF,DPC FRIC..DPC ED*DPC XSTO'DPC 101592.000 45.980 -71500 '999i250 -999 250 -999250 101592,~00 48, 20 '28,100 26.8i0 0,767 0,760 1.015~,.000 ..290 '58,500 30;5i0 ,670 '340 101592.000 54.:t70 4 O0 oiS~ 'ooo 2 · 500 29,610 0*567 o;ooo 101592:,000 50,420 .123~400 ~999.250 .999~250 999,250 101592,000 ~7.'670 '8'300 29*720 7~0 .IS Tame Verl~icatlon Llstlng ;chlumberqer las~a ComputtnO Center FLAT.DPC 5.12] DEP?.OPC 8500.000 .OP DP¢ 4!.500 s?OR:DPC 12.490 MTF.DPC 249.200 D~AG.DPC 5,360 EDN.DPC 0.597 FLAT.DPC 4.588 DEPT DPC ~OP DPC STO~ DPC MTF DPC D~AG DPC EDN DPC FLAT.DPC DMPT,DPC ROP.DPC STO~.DPC ~TF DPC EDN.DPC FLAT,DPC DEPT.DPC ROP.DPC ~TF,~C D~A~.DPC gDN.DPC FLAT'DPC DE~T,DPC ~OP,DPC STO~,DPC ~TF'DPC DR~G~DPC EDN DPC FLAT' .,DPC D~PT.DPC ~OP DPC STO~ DPC ~TF DPC D~A~ DPC EDN DPC FL~T:DPC DEPT. DPC ST0~. OPC ~T~ DPC D~AG: DPC 8600,000 22,800 0.000 241.200 60,8]0 -0.446 4.825 8700.000 32.900 !1,730 197.700 6,110 0,601 4,763 8800,000 33,600 12,51.0 230,400 7,440 ,763 8900.000 69'900 12'750 169,400 '999,250 '999,250 '999,250 9000.000 81 200 15 140 95 8O0 '999 250 '999.250 '9~9'250 9100.000 90,400: 15,750 i~9,300 -999~250 GR.DPC TVD.DDC ROP5 DPC RPM:DPC DWOB.DPC TD.DPC FOR$,DPC GR.DPC TVD.DPC ROP5.DPC RPM.DPC DWOB.DPC TD.DPC FOR$,DPC GR.DPC TVD DPC ~O~5:DPC RPM.DPC DWOB'DPC TD,DPC FOR$.DPC GR,D~C TVD,DPC ROP5,DPC RPM'DPC DwOB.DPC TD'DPC FORS.DPC gR.DPC TVD'D~C ROPS~DPC RPM,DP¢ DNOB,DPC TD,DPC FORS"DPC 'GR.DPC TVD,DPC ROP~'DDC RP~'DPC D~OB~DDC TD~DPC FORS,DPC CR,DPC ?VD DPC ROPS:I)DC RP~,DPC DWOB,DPC TD,DPC 9-DEC-1992 09:05 -999.250 7732.689 40.900 70.770 55.100 0.104 42,210 -999.250 7811.588 39.800 0.650 71.980 0.07] 22.110 -999.250 7890.665 32,200 76.260 49'600 0,!00 46,410 -999. ~ 0 .969,538 33,7 50,100 0;1~5 49'1 0 999.250 8048 -348 8: oo 95:20 '999,2~0 "999.'2 0 ,.99~, 0 0 .: oo 999'250 ,,999~250 999. 0 R206. 25 84' ~00 .!10,840 999~.~50 -999 ~ 50 GRC.DPC TIME.OPC TOTH.DDC SPPR,DPC DTOR,DPC $ORD.DPC FO~.DPC GRC.DPC TI~E,DPC TOTH,DPC SPPR,DPC DTOR,DPC SQRD.DPC FORM,DPC GRC.DPC TIME.DPC TOTH.OPC SPPR,DPC DTOR,DPC SOPD,DPC FOR~'DPC GRC,DPC TIME,DPC TOTM,DPC SPP'R,DPC DTOR~DPC SORD DPC FOR~ DPC GRC DPC TIME,D~C TOTH,DPC SPPR,.DPC DTOR,DPC $DRD, DPC FORM,DPC GRC,DPC TIME.DPC TOTH,.DPC SPPR.'DPC DTOR,DPC SQRD,DPC FOR~OPC GRC'DPC TI ~.E.DPC TOTH, DPC SPPR, DPC DTOR, DDC sO~o' D~C -999.250 84787.t41 34.540 3478.000 5.860 0.070 0.000 -999.250 10810.549 37.230 3236.000 5 0 10 ~0.843 -9 9.250 20531.582 39.500 3483.000 5.050 0.062 0.000 -999'250 31252,53! 42,170 3515,000 5.860 0'061 . 0.000 999'i1250 42683..563 0.050 ~435,000 ~999'250 2999'250 .999.250 999'250 2,070 ~500;:000 ,999,250 .999.~50 999.~50 53870,414 :150 .999.250 999~250 DATE.DPC SWOB,DPC GTF.DPC FRIC.DPC ED.DP¢ XSTO.DPC DATE.DPC SWOB.DPC GTF.DPC FRIC.DPC ED PC SWoB.DPC GTF.DPC FRIC.DPC ED'DPC XSTO,DPC DATE,DPC SWOB.DPC GTF,DPC FRIC,DPC ED.'DPC XSTO,DPC DATEeDPC SWOB,DPC GTF,DPC FRIC,DPC ED.DPC XSTQ,DPC DATE,rDPC $WOB,DPC ~TF,DPC FR~C.DPC ED.DPC XSTO.DPC DATE.DPC $~OB,DPC GTF~DPC FRIC.DPC ED.DPC PAGE{ 10 101592.000 60,070 '37.200 26.240 0.744 1,070 101692 000 130 240 -106 900 -999 250 0 297 0 000 692 000 55 65O · ,94 000 40 0,710 101692,000 .570 . I.,oo ;670 1,470 101792 000 2 0 -999 2'50 -:999 250 ,-999'250 ,o 7 I'ooo ,810 .76,300 999,250 '999,250 '999~250 1017921'000 15'220 79' 700 -999,250 -999,250 IS Tape Verification bistinq chlumberger AlasKa Computing Center ED".DPC -999.250 FF)R$.DPC FbAT.DPC -999.250 GR.DPC DEPT.DPC 9200.000 TYD.DPC ROP,DPC 96.200 ROPS,DPC STOR,DPC 8,8!0 RPg,DPC MTF,DPC 243,200 DWOB,DPC DRAG DPC -999.250 TD.DPC EDM'DPC -999.250 FORS. DPC FLAT:DPC -999.250 GR.DPC DEPT DPC 9300.000 TVD.DPC ROP:DP¢ 29.200 ROPS.OPC STO, DPC 13 910 RPM.DPC MTF]DPC 1571900 DWOB.DPC DRAG.DPC -999.250 TD.DPC EDN.DPC 0.903 FORS.DPC FLAT,DPC 1,6~5 GR,DPC DEPT.DPC 9400 000 TVD.DPC ROP.DPC 25:700 ROPS.DPC STOR.DPC ~4 2{0 RPM.DPC MTF'DPC 160:400 DWOB.DPC DRAG.DPC 2.460 TD DPC ED~.DPC 1,15~ FORS:DPC FLAT.DPC 2,173 GR.DPC DEPT,DPC 9500 000 TVD.DPC ROP.DPC "23]400 ROP5.DPC STOR,DPC 1~.250 RPM'DPC NTF2DPC !6 ,200 DWOB,DPC DR~G.DPC 4.~70 TD.DPC EDN'DPC !. 26 FOR$.DPC FLAT,DPC 2.!73 GR*DPC DEPT.DPC 9600.000 TVD.DPC ROP DPC 40,100 ROPS.DPC s?OR'DPC 13'750 'RPM'DPC MTF:DPC !56'000 DWOB,DPC DRAG*DPC :999'.250 TD:.DPC ~DN.DPC 999,~50 FOR$,DPC FLAT.DPC -999.250 ' GR.DPC DMPT DPC 9700,000 TVD..DPC ROP~:DPC 68.!00 ROPS..DPC STO~ DPC ~,!40 RP~'DPC MTF~DPC 1B~. ~00 DWOB'DPC DRAG,DPC -999,250 TD'DPC EDN,DPC ~999.250 FORS'DPC FLAT.DPC -999.250 GR~DDC D~PT.DPC 9800.000 TVD,DPC ~OP.QPC 67.100 ROPS~DPC STOR'DPC 6'310 RP~.DPC MTFiDPC 161.100 D~OO.DPC 9-DEC-1992 09:05 -999.250 -999.~50 96.~06 51 180 '9991250 -999 250 -999 250 -999.250 8370 416 45~200 115.~60 60.730 0.082 30.870 -999.250 10.980 154.10 OO8 ~2980 999,~50 0 O, 3 '999,250 000 I12 060 -999 250 -999 -999 2 0 -999 250 8725.2052 68.0~ 0 69'070 1'400 -999,2~0 o 3 ~.~o -999 :. 250 88i6,436 66.300 67.260 0.720 FORM.DPC GRC.ODC TIME.DPC TOTH,DPC SPP~.OPC DTOR,DPC SORD.DPC FOR{.DPC GRC.DPC TI{E.DPC TOTH.DPC SPPR.DPC DTOR.DPC $ORD DPC FOR~:DPC GRC.DPC TINE.,DPC TOTH.DPC SPPR,DPC DmOR.DmC SORD.DPC GRC TIME.DPC TOTH,DPC SPPR.DPC DTOR..DPC SQRD,DPC FOR~'DPC GRC,DPC TIME,DPC TOT'H,,DPC SPPR~DPC= DTOR.DPC SQRD.,DPC FOR~,DPC GRC,DPC T]ME,DPC TOTH.DPC~ DP SPPR*Dp~ DTOR, FORM,DPC ~RC,DPC TI~E,DPC TOTM,DPC SPPR,DPC DTOP,DPC -999.250 -999.250 22062.965 0.030 3418.000 =999.250 -999.250 -999.250 -999.250 3458 000 5 060 0 080 0~000 -999'250 51200.930 6.960 3490.000 4.860 8:.o7 42] 3444,000 4,740 0.;068 . 0.297 -999.250 80414'9122 _.4t2'920 ]~9,ooo .999.250 .999,250 999,250 -999.250 o:As' -999'2 0 8 0 50 XSTQ.DPC DATE.DPC SWOB.DPC GTF.DPC FRIC.DPC ED.DPC XSTQ.DPC SwO PC GT~ DPC FRI ]DPC ED.DPC XSTO.DPC ATEDPC WOB:DPC GTF.DPC FRIC..DPC ED,DPC XSTO.DPC DATE DPC SNOB DPC GTF DPC FRIC DPC .ED,DPC XSTQ.DPC ~nZE'U~C SWOB,DPC GTF,DPC FRIC,DPC ED..DPC XSTO,DPC DATE.DPC SWOB,DPC GTF,DPC FRIC,DPC ED,DPC XSTQ'DPC DATE,DPC SwOB'DPC G?F.DPC FR!C.DPC PAGE' '999.250 1018~.000 .12 '110 ,300 '999.250 -999.250 -999.250 101892 000 59 .180 i26 ?00 31 970 52 o 0 0 56 ~90 'II: o° lo o oo 1018~2,000 0,210 ~7:'300 8;390 ~,0 101892,000 56,920 .121,800 ~999,250 .999,250 999'250 I0~792,000 i~999'250 '46~;900 '999,250 0'282 0,000 o279~'ooo 2'110 22,400 999 ,IS Tape Verification ListinQ ~chlumberger AlasKa Computing Center DRAG DPC '999.250 TD.DPC EDN:DPC -999.250 FORS,DPC FI, AT.DPC -99q.250 GR.DPC DEPT.DPC 9900.000 TVD.DPC ROP.DPC 61.300 ROP5.DPC STOR.DPC 6.160 RPM.DPC MTF.DPC 70.500 DWOB,DPC DRAC,DPC -999,250 TD.DPC EDN DPC -999 250 FO~S,DPC FLAT:DPC '999:250 GR.DPC DEPT.DDC 10000,000 TYD.DPC ROP DPC 80.300 ROPS.DPC STO":DPC ~:520 RP~,DPC DPC 6 9OO DwO DEPT.DPC lO~O0.O00 TVD.DPC ROP DPC 70.900 ROPS,DPC STOR:DPC 6'660 R~M.DPC PTF,DPC 266 600 DWOB.DPC DRAG.DPC -999~250 TD~DPC EDN.DPC -999.,250 FOR$..DPC FLAT,DPC -9991250 GR.DPC DEPT.,DPC 10200,000 TVD,DPC STOR,DPC 700 RPM,DPC "TF'DPC ,197,400 DWOB,DPC DRA~,DPC 999'250 TD,DPC EDN,DPC -999,250 FORS,DPC FLAT'DPC -999,250 GR,DPC D~PT.DPC 1.0300,000 TVD,DPC ROP.DPC 31 000 ROP5,DPC S?O~,DPC 8 980 RPM.DPC DPC 197 300 ,DDCC ~T'~, . DWO:B'DP DRAG,DPC 1 280 TD. EDN,DPC 0 967 FORS,DPC FL~TiDPC 0,5~0 GR'DPC D~PT DPC 10400.,000 TVD,DPC ~OP~:DPC '5i.,300 ROPS~DPC STO~,DPC 8.840 RPM.DPC MTF.,DPC 78,:i00 DWOB,DPC DRA~,DPC -999,250 TD'DPC ED~' DPC 0,486 FO~$,DPC FLAT::DPC 0,412 GR.DpC 9-DCC-1992 09:05 -999.250 SQRD.DPC 0.900 FOR~.DPC -999.250 GRC.DPC 8907.506 TIME.DPC 63.800 TOTH.DPC 75.780 SPPR.OPC 0.720 DTOR.DPC -999.250 $ORD,DPC 0.840 FOR~.DPC -999.250 GRC,DPC 8998 357 TIME.DPC 76~200 TOTH,DPC 66,700 SPPR.DPC 0.970 DTOR,DPC -999.250 SORD.D~C 0.870 FOR~.DPC -999,250 GRC*DPC 9089 174 TI~E.DPC 69i100 TOTH,OPC 77 620 SPPR.DPC 1,~00 DTOR.DPC '999. 50 $ORD,DPC 0,800 FORM,DPC -999.250 GRC,DPC 0 151 -o:oo -999.250 79613 563 3 540 -3O 000 0 120 0 136 0.002 -999.250 4 90 2100.000 0.180 0.164 o. Oo6 -999'250 5424 800 6i420 2078 000 0 0 5O , 42 TIME.DPC 11578.482 ~],~00 TOTH.DPC 7.960 67,150 SPP"'DPC ~096,000 ~ ~00 DTOR.DPC 0.:270 : 50 SORD.DPC 0.149 1.750 FOR~,DPC . 0.~006 -999,250 GRCZDPC 999.250 9270, 59 TINE,iDPC 28878.781 31.i~0 TOTH.DPC 11.970 rO SPPR,DPC 1906,'000 ]~i850 DTO 'DPC 2'680 . 3~.~15 SOR~,.DPC 0.096 90 FO~M'DPC 0,030 ,999'250 GRC,DPC -999,250 9361.270 TIME,DPC 25.400 TOTB,DPC 81,1320 SPPR,.DPC 8, 20 DTO 'DPC 90 S~D~iDPC -999,250 GRC*DPC 56143.578 18.990 1942.!000 2.460 0.122 0.462 -999,250 ED.DPC XSTO.DPC DATE.DPC SWOB.DPC GTF,DPC FEXC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB,DPC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC ATE DPC ~WOBiDPC GTF DPC ED x o: Pc D~TE,DPC S OB'DPC GTF.DPC FRiC.DPC ED'DPC XSTO.DPC DATE,DPC SWOB,DPC G:TF.DPC FRiC~DPC ED~DPC XSTO2DPC ATE.DPC ~OB,DPC GTF,DPC FRIC,DPC ED.DPC XSTO.DPC PAGE{ 12 4 101792,000 2,400 48,100 999,250 0,976 0,000 10279~:000550 ? .ooo 0~5 0,000 102892*000 0,70 250 70? o;ooo 102892,000 0'9 0 75,600 '250 '99t,604 o,ooo I02892'~000 4,300 ~8.720 0,964 o;ooo 102892'000 4~, 480 -7 .;400 * 1400 oo .IS Tape Verification ListinQ chlumberger AlasKa ComPutino Center D~PT DPC ROP~DPC STOP.DPC MT~.DPC D~AG.DPC ED~.DPC FLAT.DPC DEPT.DPC ROP DPC $?OR~DPC MTF.DPC DRAG.DPC EDN DPC FLAT:DPC DEPT.DPC EDP DPC ~TF.DPC DRAG*DPC MDN,DPC FL~T.DPC DEPT,DPC ROP.,DPC STOR'DPC ~TF,DPC DRAG,DPC EDN.DPC FLAT.DPC ,0P*DPC STO~'DPC ~TF,DPC OEPT,DPC ROP OPC 5TO~ DPC ~TF DPC D~A~ DPC ED~DPC FLAT DPC 10500.000 17.800 8.710 182.400 1,980 0748 0:4!2 10600000 '999i250 -999250 -999,250 -999,250 -999.250 -999.250 10700,000 =999 250 -999.250 -999.250 -999.250 -999.250 10800.000 999~250 -999,250 -999 250 -999250 10900.000 -999,25.0 -999,250 -999,250 '999,250 '999,~50 '999, 50 !1000..000 -999'250 -999.;250 -999'250 -999,250 -999,~50 -999~50 9-DEC-1992 09:05 ** ~D OF DATA ** TVD DPC 9452.477 TIME.DPC ROPS:DPC '18.200 TOTH.OPC RP~4.DPC 83.290 SPPR.DPC DWOB.DPC 37.600 DTOR~ DPC TD.DPC 0.092 SORD.D~C FORS. DPC 69.280 FOR~ DPC GR.bPC -999.250 GRC:DPC TVD.DPC -999.250 TIME.DPC EOP5 DPC -999.250 TOTH DPC RPM:DPC -999.250 SPPR:DDC TD.DPC -9~=."250 $ORD.DPC FOR$.DPC -999.250 FORM,DPC GR.DPC -999.250 GRC.DPC TVD.DPC -999250 TI~E.DPC ROP5 DPC -999;250 TOTH. DPC RP~{:DPC -999.250 SPPR,DPC DWO8.DPC -999.250 DTOR DPC TD.DPC -999.250 SORD;DPC FOR$.DPC 2099 ~50 FOR{~, DPC GR,DPC 999~ 50 C}{C. DPC TVD,DPC ~999.~50 TIME,DPC ROPS. DPC .999' ~50 TOT}{,D~C ~P~I,DPC ~999~250 SPPR,DPC DWOB~DPC 1999,250 DTOR. DPC TD' DPC .999.250 SORD*DPC FOR$.DPC 999*250 FORM.DPC GR'DPC -999.~50 GRC,DPC TVO.DPC -999.~0 TI~E.DPC ~C)P5, DPC '999. 0 TOTH,DPC RP~.DPC '999.i~09 SPPR.DPC DWOB'DPC "999. 0 DTOR'DPC TD'DPC "99 · 0 =$ORD'DPC FOR~$.DPC -999. ~0 ~O~,~.DPC GR.DPC '999* 0 GRCeDPC TVD. DPC -999, ~.50 TI E,DPC ROPS.-DPC -999~ 250 TOTH,DPC ~PM,DPC '999'250 SPPR~DPC DWOB'DPC '999,250 DTOR.DPC . TD,DPC ~999,~50 SORD' DPC F oR$,DPC 999.250 FORM.DPC GRiDPC '999~250 GRC,DPC 77167.391 24.540 2052.000 2.460 0.070 -0.200 -999.250 999.250 999.250 999.250 '9 =9 o 0 -999 ~50 2999; 50 999.250 999.=250 -999.250 -999.250 :999.:250 .999.250 ,999.250 .999.250 .999'250 .999'250 999'~50 999.250 .999.250 1999':250 .999.250 ~999.:250 .999'~50 999..250 .999.250 2999.250 ,999,250 ,999.250 .999'250 .999.250 DATE.DPC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC DAT£.DPC SWOB.DPC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB.DPC GTF.DPC FRIC.DPC ED.DPC XSTO.DPC DATE.DPC SWOB.DPC GTF.DPC FRIC'DPC ED.DPC XSTO"DPC DATE*DPC SWOB.*DPC GTF.DPC FR/C.DPC ED.DPC XSTO.DPC DATE,DPC SWOB.DPC GTF.DPC 'FR!C*DPC ZO'OPC XSTQ,DPC PAGE: 102892'000 40.240 18,500 766 0.000 -999 250 =999 250 -999 250 -999 250 -999 250 -999 250 -999.250 :999,:250 999,250 :999,.250 .999'250 999.250 -999.250 -999~250 ~999.250 -999'1250 -999e250 -999'250 %999,250 .999,250 999';250 -999,250 :999,~:~0 999,250 '999,250 '999'250 IS Tape Verification Listing chlumberger AlasKa Computing Center **** FILE TRAILER **** FILE NAME : ADV .00! SERVICE : DPC V~RSION ~ 2 0 DATE : 1~/09/92 MAX R~C SIZE : 1024 FILE TYPE : LO LAST FILE : , SERVICE NAM~ : DPC2 DATE : 12/09192 O~!~IN : ~OV TAPE NAME : CONTINUATION # : PREVIOUS TAPE CO~ENT : Anad~ill LIS tape ***~ REEL TRAILER SERVICE NAME : DPC2 DATE : '12109192 ORIGIN : ADV REEL NAME , : TAPE! CONTINUATION ~ P~EVIOUM REEL COMMENT ~ ANADRIbL LIS Tape 9-DEC-1992 09:05 PAGE: 14 ALASKA COMPUTING CENTER *------- SCH~UMBERGEP --,-----~ cOMpANY NAME ) ARCO A~ASKA~, INC, WELL NAME FIELD NAME ~ POINT MC!NTYRE BOROUGH ~ NORTH SLOPE STATE AP1 NUMBER ~ 50-029-22288-00 REFERENCE NO = 92~4! COI, ,i iDE) IIAL R'EC£1V£D ,chlumberger Alaska Computing Center 3-DEC-1992 07103 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 92/12/ 3 ORIGIN : FLIC REEt, NAME : 92641 CONTINUATION # : PREVIOUS REEL { COMMENT { ARCO ALASKA, INC..POINT ,CINTYRE,P{-20,50-029-22~88-O0 **** TAPE HEADER SERVICE NAME : EDIT DAT~ : 92/12/ ORIGIN { FLIC TAP~ NAME : 92641 CONTINUATION # { ! PREVIOUS TAPE : coMMENT : ARCO ALASKA, INC.,POINT MCINTYRE,P!-20,50-029-2228~-O0 T~PE HEADER POINT MCINTYRE UNIT ~WD/MAD LOGS W~LL NAME: APl NUMBER: OPERATOR:. · bOGGING COMPANY: T~P~ CREATION DAT~: #, jOB DAT~ J~B NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION:, TOWNSHIP{ ~ANG~I rwt: EbEVATION(FT FROM ~SL O) KELLY BUSHING: DERRICK FLOOR.' G~OUND LEVEL: Pl 0 ARC AbASKA 03-DEC-92 # WELL CASING RECORD !ST STRING ~MDSTRING BIT RUN 1 BlT RUN 2 BlT RUN 3 92641 92641. 9~641 JACKSON JACKSON PERRY JOHNSON JOHNSON JOHNSON 16 12M 14E 5! OD 51]00 9,00 OPEN .OLE CA IN~ DRILLE~S BIT SiZE (IN) SIZE (IN) DEPTH (FT) 13..)75 3473,0 PAGEI I 'RECEIVED DEC 3 1 199~ Alaska Oil & 0~ OOn~. Commlmsl~ Anohoraae ,IS TaPe Verification Listing ,chlumberoerAlaska Computing Center 3-DEC-1992 07:03 ]RD STRING PRODUCTION STRING # RFMARKS: FIELD ENGINEER'S REMARKS: WASH DOWN ~o, ~0!i' ro ~e' ' ' DRILL FROMo~96~0 9i97'. ' · ,,,,,,,,, RU. ,,,,,,,,,, Ro. 64o ' · *****~*** 5WP RUN 003 BIT TO RES. 28.92', BIT TO GR 39 34'. BIT TO DEN. 95.75', ~IT TO NEUT '~01.9§' WASH DOWN FROM 9640' TO ~0~7'.' ° D~ILL FROM 10~37' TO ******************************** DATA FROM DOWNHOLE MEMORY. RECORDED RATE AT ~0 SECONDS, DOWNHOLE SOFTWARE V4.0C $ PAGE: **** FILE HEADER **** FiLE NAME ~ EDIT ,001 SERVICE : FLIC VERSION : O01A07 DAT~ : 92/12/ 3 MAX REC SIZE : ~024 FIL~ TYPE : LO LAST FILE : FILF HEADER FIL~ NUMBER: 1 ~DITED MERGED MWD Depth shifted and clipped curves; all bit runs merged,~ D~PTH INCREMENT 0.5000 * # FILE SUmmARY TOOL C~DE START DEPTH 7086'0 $ BAS~LINE CURVE FOR. SHIFT8~ GR CU'PVE S~IFT DATA (MEASURED DEPTH) BASELINE DEPTH 10389.5 10~79.0 STOP DEPTH 1:0503,0 ----------EQUIVALENT UNSHIFTED DEPTH---------- ~ W D 103~2,5 10311.5 10273.5 I8 ?a~e Verifieatlon T, imtjna ehlumberoer AlasKa ComputXn~ Center 10266 0 10251i0 10243 5 10203.5 !0187.0 10164.0 10129 0 10093~0 10063.5 10010.0 9998.0 9988 0 9950 0 9939 0 9~95 0 9867 5 9835 0 9798 0 975815 9747 0 9732 0 97!8,~ 9662 0 9657 0 9652 0 9639 5 961 5 960 0 9590 ~ 9577 0 9558.0 9556 0 9545 5 9538,5 9535:~ 9530 95~9.5 9515.5 9490,5 9363.0 9322,5 9314 5 9009.0 8948,0 8804.0 8745,5 8667,5 8645,0 8584.0 8514,5 10260.0 I0245.5 10239.0 10220.5 10200.0 1O185.5 10162.0 10128.0 10090,5 10060,5 10006,0 9993.5 9984.0 9957,~ 9947. 9917,0 9897,0 9867,0 9835.5 97995 9746.5 9734.5 9721,0 9656.5 9652'5 9639,5 96{4,5 9607,~0 9592,5 560 9558,0 9547.0 9540,5 9536.5 9529,5 9520,$ 9490,5 9363,5 9323.0 9314.0 922:8.0 9010,0 8948'~ 8804,0 8744,5 8667.5 8645'5 8583,5 8512.0 3-DEC-199~ 07:03 PAGE: Tape verification Listing chlUmberger Alaska Computing Center 3-D. ~;C-1992 07:03 PAGE: 8486,5 8447,0 8356,5 o 8260 5 7986 0 7806 0 7703 5 7687 5 7591S 7581 5 7538 5 7525 0 7495 5 7442 5 7333~0 7272,5 7208,0 7153,5 7134,5 loo,o ~ERGED DATA SOURCE PMU TOOL CODE ~m~mmmmmmmmmm ~WO MAD 8487,5 8448.5 8357.0 828 5 8262,0 7991.0 7811.0 7709,5 7694.5 7589,5 7579.0 7540.0 7529.5 7501,0 7447.0 7342,0 7281.0 7213.0 7158.0 7137,5 103,0 BIT.RUN NO, M~RGE TOP MERGE BASE i 7086,0 8896,0 I 8896,0 9197,0 9197,09640,0 · 1 Io ?:o o o .:o THE DEPTH SHIFTS ABOVE REFLECT OPEN HOSE GR TO CASED HObE GR FROM WESTERN,ATLAS DATED 29-0CT-92,~" Abb OTHER URvES WERE CARRIED WITH THE GR SHIFT, IS~'NOTED XN THE MERGE TABLE ABOVE :THIS FIbE CONTA, INS SECTIONS OF MAO DATA. IT .AS BEEN'INCLUDeD HERE TO A 9 PROVIDE A CONTINUOUS LOG AS NO MWD DATA 'WAS AVAIb BLE OVER THESE INTERVALS. $ # LIS FORMAT DATA Tape Verification Listing chlumberger Alaska ComPutin~ Center 3-DEC-1992 07:03 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** ''''''''''''''''''''''''''''''E REP~ CnDE ¥ 1 66 0 2 66 0 4 66 5 66 7 65 9 65 11 66 25 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ** SET TYPE - CHAN ** ...................-.,,...............................,--.............................- NAME SERV UNIT SE~ ~CE APl APl AP1 AP1 FILE NU B NUMB SIZM REPR PROCES$ ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) .................--.,,,,..-,,............-...--....... ..... .,...........,..........,. ..... DEPT FT 54 , 000 O0 0 I i 1 4 6 0000000000 RHOB MWD G/C3 54~99~ O0 000 O0 0 1 ! 1 4 68 D~HO ~WD G/C] 548992 O0 000 O0 0 1 1. I 4 68 PEF MWD BM/E 548992 O0 000 O0 0 I I I 4 68 CALN MWD IN 548992 O0 000 O0 0 1 i 1 4 68 NPH! MWD PU-S 54899~ O0 000 O0 0 ! 1 1 4 68 RA MWD OH~M 548992 O0 000 O0 0 1 1 ! 4 68 RP ~WD OHMM 54899~ O0 000 O0 0 I 1 1 4 68 ROP ~WD F/HR 54899~ O0 000 O0 0 I 1 I 4 68 C~ MWD GAPI 54899~ O0 000 O0 0 1 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** AL~..~WD 999,250 NPHI:i. MWD ROP.MWD 18,109 GR'MWD DEPT. ~0400,000 ~HOB,HWD CALN'~WD 8,549 NPHi"MWD ~OP,MWD 17.3~4 GR,MWD 999,250 999,250 ~.A,~WD 999,250 -999:: 0 RA,MWD 10].542 -99 2500 P 2:5 ~p.'~wD 2.099 ~p.~WU -999 '250 3,7318 O. IS Tape Verification histing chlumberger AlasKa Computing Center DEPT, 10300,000 RHOB.MWD CALN.MWD 8,602 NPHI,NWD ~OP.MWD 31,196 GR.MWD DEPT, i0200,000 RHOB,MWD CALN,MWD 8.644 NPHI,MWD ~OP,MWD 64.672 GR,MWD DEPT. 10100.000 RHOB,MWD C~LN,MWD 8,627 NPNI.MWD ~OP,MWD 73.172 GR.~WD DEPT. iO000,O00 RHOB.MWD C~LN MWD 8, 714 NPHI,MWD DEP? 9900,000 RHOB,MWD ¢ILN~MWD 8,79~ NPHI,MWD ROD,MWD 68,809 GR.MWD DEPT' 9800.000 RHOB,MWD cASN.MWD 8,693 NPHI.MWD ~OP'MWD 67.405 ~R.MWD DEPT, 9700,000 RHOB.MWD CiLN,MWD ~:680 NPHI,MWD ~OP,MWD 6 563 G~,MWD C~OP,MWD ~4,250 GR'MWD D~PT. 9500.000 RHOB'MWD CA~N ~WD -999,250 NPHI'MWD .OP:_WD 25,4'78 GR.MWD DEPT' ~400,000 RHOB'.MWD DEPT, 9300,000 RHOB'MWD C~SN, ~DMW .... -999,250~ . NPHI'MWD ~:OD,MWD 45,569 GR-MWD DEPT. 9200.000 RHOB,MWD CALM MWD '999,250 NPHI~MWD POP:MWD 5~,926 GR.MWD D£PT- 9~00,000 ~HOB.MWD CALNi~WD '999'::250 NPHI,MWD ~OP MWD ~4,637 GR,~WD 3-DEC-199~ 07:03 2.276 DRHO.MWD -0,011. 0,247 RA,MWD 3.176 20,890 2.470 D.HO..WD -0:~14 0.206 ,~,MWD 5 80 47.594 ~.505 DRHO.MWD 0.~6 0.232 RA,MWD ~1 9 35.273 ' 2.~9 DRHO,MWD -0.045 O. 6 R~.MWD 1.717 48.{97 ~!i49 DRHO,MWD -0.036 27 RA,MWD 73,086 22 27 2.876 DRHO,MWD -0 067 0'351 RA.MWD 63,016 ~.584 DRHO,MwD -0 ~!0 0.!97 RA,MWD 57,688 ' - . .99: 50 R!:MWD 175,432 -999 ~50 DRHO,MWD -999 250 -999'~0 RA:MWD ~.B37 i:14i539 -999.250 DRHO.,MWD -999,250 -999'2~0 105,395 -999.250 DRHDoMWD -999,.~50 -999.250 RA.MWD 'I.'764 99..51~ PEF.MWD ~P.~WD PEF,MWD RP.~WD R ~WD PEF.NWD RP.MWD PEF.~WD PEF.MWD PEF,MWD RP.MwD PEF'MWD RP,MWD PEF.M~D RP,MWD PEF.MWD RP.MWD PEF,MWD RP.MWD PEF.MWD RP,MWD PEF.MWD PAGEI ]:4'4 066 2.900 5.787 3.098 ~.04g ! 263 4.702 119,063 11.699 2!.477 53 -999.,250 2,469 -999.250 -999.2:50 1:545 -999"250 3-455 -999'250 2'659 -999,250 1.756 .chlUmberger .lasKa Computin. Center DEPT. CALN.MWD ~OP'MWD D~PT, CAGN,MWD ~OP.MWD D~PT, CA~N.MWD ~OP.MWD C!LN.MWD DEPT. CmLN.M~D ROP,MWD D~PT, CALN,MWD D~PTo CALN,MWD POP,MWD C~SN CAbN,~WD ~OD.~WD D~PT ROP M~D D~?. ~[N.MWD C~Op. MwD D~PT OP.MWD DEPT' C~.LN,M~D 9000.000 -999.250 74.327 8900.000 -999.250 78.375 ~800.000 -999.250 ~42o445 o.ooo 9,250 B600,O00 -999.250 1.76.860 8500.000 -999 250 !77:019 400,O00 ~999,250 ~09o43] 8300 000 -999 250 ~40 647 8200000 !79 97 8100.000 -999,250 211,637 8000,000 '999,250 ~95.6~7 7900,000 -999,~86~ 50 201. 800,000 Z999.250 I68,449 RHOB.MWD NPHI.MWD RHOB.~WD NPHi.MWD ~R.MWD RHOB.MWD NPMI. MWD GR:MWD RHOB.MWD NPHI.MWD GR.MWD RHOB,MWD NPHI.MWD GR.MWD RHOB.MWD NPHIMWD RHOB,MWD NPHI,MWD GR.~WD RHOB.MWD NPHI.MWD GR,MWD RHOB,MWD NPHi~MWD GR,~WD RHOB.MWD NPHI.MWD NPHI'MWD GR.MWD RHOB,MWD NPHI,MWD ~R,MWD RHOB.MWD NPHI,MWD ~R.MWD 3-DEC-1992 07:03 -999.250 DRHO,MWD -999o250 -999.250 RAoMWD 2.531 105.777 -999.250 DRHO,MWD -999.250 -999.~50 RA.MWD 2.27! 10~.727 -999o~50 DRHO,~WD -999.250 '999.250 RA.MWD 2.591 92'006 -999.250 DRHO,MWD -999.250 -999o250 R.A.MWD 2.t36 97.305 -999 250 DRHO.MWD -999.250 '999i250110648 RA.MWD 3.33~ -999.250 DRHO.MWD '999 250 -999.~50 RA'NWD 106, '999.~50 DRHO ~WD '999.250 102.750 '999.250 DRMO,MWD -999.250' -999,~5:0 RA,MWD 3.098 101. 0'3 -999.250 DRHO,.~MWD -999250 -999,250 RA.MWD 2:224 88.990 -999'250 DRHO,MWD -999 ~50 -999.~§0 PA,MWD 99'656 -999,250 DRHO,MWD -999"~50 -999,~50 ~A,MWD 2°904 102~84~ -~999,250 DRHO,MWD -999,~50 '999'250 RA,MWD 2.536 101.512 999 50 DRHO,MWD~ -99 50 PEF.MWD RP.MWD PEF.MWD RP.MWD PEF.MWD RP.MWD PEF.MWD RP.MWD PEF.MWD RP.MWD PZF.M~D RP.MWD PEF'MWD RP,MWD PEF,MWD RP.MWD PEF..MWD RP.MWD PEF.MWD RP,MWD PEF MWD RP:MWD PEF.MWD RP'MWD PEF.MWD RP.MWD PAGE', -999,250 2.509 =999.250 2.157 =999.250 2.552 -999.250 1.993 -99~,250 ,956 '999,~50 2.124 -999.250 2.743 -999,250 2,897 -999,250 2,547 -999'250 2,36! -999,250 2'902 -9,9. 2, ,i 4 3 Tape Verification Listing chlumberger Alaska Computing Center DEPT, 7700,000 RHOB,MW~ C~LN.MWD -999,250 NPHX.MWD ~OP,VWD 194,136 GR,MWD OEPT. Z600.O00 RHOB,MWD CALN,MWD 999,250 NPHI,MWD ~OP.MWD 194.124 GR.MWD D~PT. 7500.000 RHOB.~WD CALN.MWD -999,250 NPHI.~WD ROP.MWD 215,251 GR,MWD DEPT. 7400,000 RHOB,MWD C~LN MWD -999,250 NPNI.MWD ~O~:~WD !76.999 GR,MWD DEPT. 7300,000 RHOO.MWD CALN,MWD -999,~50 NPMI,MWD DEPT.. Z200,O00 RHOB,MWD C~bN.~WD 999,250 NPHI,MWD ~OP.MWD 312.797 GR,MWD DEPT. 7~00.000 RHOB.MWD CALN MWD -999 250 NPHI.MWD ROP' ,MWD -999:~50 GR,MWD DEPT, 7090,000 RHOB,MWD CALN.~WD -999,250 NPHI'MWD ~O~,MWD -999,250 GR.~WD END OF DATA **** FILE TRA. I[~ER FILE NAME : EDIT ,001 SERVICE ~ FLIC V~RSION : O0~A07 DATE ~ 92/~/ 3 MA~X REC SIZE : 1024 F~L~ TYPE ~AST FILE 3-DEC-1992 07:03 -999.250 DRHO.MWD -999.250 RA.MWD 109.~95 -999,250 DRHO,MWD -999,250 RA,NWD 93.677 - 9. 50 R~.~WD ~,~0] -999.250 DRHO,MWD , 40 -999.250 DRMO.~WD -999,250 RA,MWD 6~.783 -999,250 , DRHO'gWD -999,250 RA,MWD -999.250 DRHO,MWD -999.250 2.70~ -999.250 1.927 -999.250 2.55! -999.250 4.26~ -999.250 3.652 -999 250 '999~250 2,373 -99~.250 -99 .250 PEF,.wD RP.MWD PEF.MWD RP.MWD PEF NWD RP~MWD PEF.NWD RP.MWD PEF.NWD RP.MWD PEF.MWD RP,MWD PEF,~WD RP'MWD PEF,MWD RP.~WD PAGE: -999.250 2,517 -999,250 1,601 -999.250 2.362 -999,250 4.021 -999.250 3.246 '999.250 2.7~2 '999.250 '999,250 ,IS Ta~e Verl~lcatio~ Listln~ ,¢~lUmher~er ~las~a Co~utt~C Center ]-DEC-1992 07:0] PAGE: **** FILE HEADER **** FIL~ NAHE : EDIT .002 S~RVICE : F5IC VERSION : 00iA07 DATE : 92/12/ 3 MAX AEC SIZE : !024 F~LE TYPE ~ LO LAST FILE ~ FILE NUMBER 2 Curves and log header data for each bit run ~n separate f~les,, DEPTH INCREMENT: 0.5000 FTLE SUMMARY VENDOR TOOL CODE START DEPTH CDR 086.0 $ ~OG HEADER DATA DAT~ bOGGED: SOFTWARE SURFACE SOFTWARE VERSlON~ DOWNHOLE SOFTWARE VERSION~ DATA TYPE (MEMORY OR REAL-TI~E): · P DRILLER (FT): TD LOGGER(FT)~ TOP LOG INTERVAL CFT): BOTTOM LOG INTERVAL BIT ROTATIONAL SPEED ~OLE INCLINATION (D~G) MINIMUM ANGLE: MAXIMU~ ANGLE: TOOL STRING CTOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH BOR~HOLE CONDITIONS ~UD TYPE: ~UD DENSITY (LB/G): ~UD VISCOSITY ~UD STOP DEPTH 9197,0 2g'ocT'92 FAST 2,3D V4.0 MEMORY gt97.0 9197o0 7086'0 9197.0 RGS022 10,10 IS Taoe Verification L~st~nq ehlumberger Alaska Computing Center 3-DEC-1992 o7;O3 ~UD CHLORIDES FLUID bOSS ~AXIMUM RECORDED TEMPERATURE (DEGF): RESXSTIV!TY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (~T)~ MUD AT ~AX CIRCULATING T~PER~TURE~ ~UD FXST~ATE AT MUD CAKE AT 150.0 i,750 N~UT~ON TOOL MATRXX: MATRIX DENSlTY~ HOL~ CORRECTION (IN)) TOOL STANDOFF (IN)) ~W~ FREQUENCY (HZ): ~E~ARKS: SANDSTONE 2.65 8.500 ~', BIT TO GE 52,42' BlT TO RES 42.~v TO ~896 WASH DDWN ~ROM . DATA FROM DOWNHOLE MEMORy, RECORDED RATE ~T 30 SECONDS, DOWNHOLE SOFTWARE V4.0C $ # i L.:S FORMAT DATA 55,0 PAGE: 10 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB #* TYPE REPR CODE VALUE ! 66 2 66 0 3 73 20 4 66 5 66 6 73 7 65 ii 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 IS Tape Verification Listing chlumberger A18ska Computing Center 3-DEC-1992 07:03 PAGE~ ** SET TYPE - CHAN ** '''''''''''''''''''~''''''''''''''''''''''''''''''''''''''''N'MF N T VI API AP! AP) AP1 FILE MB N ;B'''''''''''''''''''''.IZ RE PROCESS .... ' ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELaM CODE (HEX) --~-wm--m~---m-----------~--~-l----------~---~------~--~-~------~---~-------~-~------- D~PT FT 548992 O0 000 O0 0 2 ! ~ 4 68 0000000000 ATR ~W~ DH~M 548992 O0 000 O0 0 2 I 1 4 68 0000000000 P~R LWI OHM~ 548992 00 000 00 0 ~ 1 ! 4 68 0000000000 ROP~ LW1 F/R~ 548992 O0 000 O0 0 2 ! ! 4 68 0000000000 G~ LWI GAPX 548992 00 000 00 0 2 1 ! 4 68 0000000000 ** DATA ** ATR.LW1 -999,250 PSR.bWl -999.250 ROPE.LW1 DEPT. 9.197.500 G~.LW1 999.250 D~PT. qlO0.O00 ATR'LW1 1.758 PSR.bW1 1'738 ROPE.LW! G~,LWl 99,419 ATR.LWl 2.508 PS~.LWl ~'4~4 ROPE'L~I DEPT 9000 000 G~:LWl 106:873 DEPT, 8900,000 ATR'bW1 2,267 PSR,bWI 2,128 ROPE.bW1 G~,bWl 103'177 DEPT 8800. 000 ATR'LW1 2'595 PSR.' bWI 2.56t ROPE.LWt DEPT' 8700.000 ATR,LW1 2,!33 PSR,LWI 1,995 ROPE,LWl G~,LWl 92.926 8600,000 ATR'~I 3,331 PSR,5WI 2,958 ROPE,LWl og.so D~PT' 8500.000 ATR,LW1 2,272 PSR,'bWI 2.:199 ROpE.LW1 O~*l~Wl !06'947 D~PT 8400,000 ATR,LW1 2,785 PSR,LWl 2.623 ROPE.LW1 O~:nWl 104,394 8300,000 AT~',bW! 3,001, PSR,bWX 2'778 ROPE.LWI DEPT DEPT.' 8200,000 ATR'LWl 2,565 PSR'bWt 2'493 ROPE.L'Wi Ge.LW'I 101,534 . D~PT, 8100 000 ATR.LW1 2,510 PSR,LWI 2,401 ROPE.LWl DEPT, 8000'000 ATR,LWI 2,746 PSR,LW! 2.614 ROPE,'LWl GR,LW! I07,300 25.604 83.720 76.087 68,18i 142,445' 211,264 176.861 177.019 146,147 172'562 185,844 Tape Yerlftcatton Listing chlumberger Alaska Computing Center DEPT. 7900.000 ATR.LWl G~.LWl 104,275 DEPT. 7800.000 ATR.LWl GR.LWl 109.555 DEPT. 7700.000 ATR.LWI Gg.LWl 91.093 D~PT. 7600,000 ATR.LWi GR,LW! 95.658 DEPT, 7500. 000 ATR,LW! GR,LWl 85:486 D~PT 7400.000 ATR.LWI G.:L~I 91.487 73 ATR.LWl D~PT 00000 DEPT. 7086.000 ATR.LWl GR.LWl 64'556 VERSION t O01AO7 DATE ~ 92/!2/ 3 ~AX REC SIZE : 10~4 FILE TYPE ~ LO LAST FILE ~ **** FILE HEADER FILE NAME : EDIT ,003 SERVICE : FLIC VERSION : 001A07 DAT~ { 92/!2/ ~AX REC SIZE : 1024 FILE TYPE : LO 3-DEC-1992 07:03 2,558 PSR,LWl 2,170 PSR,LWI 2.671 PSR,LW1 1.920 PSR.GWl 2,425 PS~,LW1 4,440 PSR,bWi 3,463 PSR.LW1 2,883 PSR.LW1 2,464 PSR'GW1 2.369 2.028 2.318 1,423 2.156 3.944 3.025 2.727 2.669 -999,250 PSR,LW! -999,250 ROPE.LWl ROPE.LWl ROPE.LW! ROPE.LWl RoPE.Lwl ROPE.LW1 ROPE.LwI ROPE.LWI ROPE.LW1 PAGE: 12 188.234 185.699 247.768 194.1~6 160,002 168,840 !83,339 206,682 -999.250 -999,250 IS Tape verification Listing chlumberqer Alaska ComPuting Center 3-DEC-1992 07=03 PAGES 13 F~LE HEADER FXLF NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RU~ NUMBER: DEPTH INCREMENT: 0.5000 # F)LE SUMMARY VENDOR TOOL CODE START DEPTH ~R 9640, S LOG H~ADER DATA DATE 50GGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNROLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-Ti~E): TD D~ILLER TD LOG~ER(FT): BOTTO" LOG fNTERV. AL (FT tit ~D?A?IONAL SPEED ~Db~ INClINAtION (DEG) ~XIMUM STOP DEPTH TOoL STRING (TOP TO BOTTOm) VENDOR TOOL COD~ TOO[, TYPE ~ ITY ~ORENOLE AND CASING DATA OPEN HOLE BI~ SIZE DRILLERS CA~ING D~PTH(FT): BOREHOLE CONDITIONS ~UD TYPE: ~[ID DENSITY ~UD VISCOSITY MUD C~LORIDES MAXIMUM RECORDED TEMPERATURE (DEGF)~ RESISTIVITY (OH~'M). AT T~MPERATURE (DEGF): UD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: ~UD FILTRATE AT (MT)~ ~UD CAKE AT NEUTRON TOOL MATRIX: MATRIX D~NSITY: 29-OCT~g2 FAST 2,3D V4 0 0640.0 9640.0 9{~97.0 9640.0 TOOL NUMBER RGS022 8.500 3473.0 10,!0 15 0,0 ,750 55.0 SANDSTONE 2.65 Tape verification L~$ting ~IcShlumberger. Alaska Com uting Center 3-DEC-1992 07:03 HO!,E CORRECTION (IN): 8.500 TOOL STANDOFF FWR FRFOUENCY (HZ): REMARKS~ ********** LWD RUN 002 ********** BIT TO RES. 1! ' DRILn FROM 919~~8T6 .XT9640 lO OR DATA FRO~ DOWNHOLB MEMORY RECORDED RATE AT 30 sEco~6s. DOWNHOtE SOFTWARE V4.0C LIS FORMAT DATA PAGEI 14 DATA FORMAT SPECIFICATION RECORD ** SET TYPE TYPE REPR CODE 1 66 0 2 66 0 3 73 20 4 66 { 11 66 12 68 13 66 0 14 65 FT I5 66 68 16 66 1 0 66 ** SET TYPE - CHAN *~ NAiF SERV UNIT SERVICE API AP! API API FIL~ NUMB NUMB SIZE REPR PROCESS ID ORDER # hOG TYPE CSA$S MOD NUMB ,$AMP ESEM ~ CODE (HEX) DEPT FT ~4899~ O0 000 O0 0 3 ~ ! 4 68 0000000000 ATR Lw~ OHMM 548992 O0 000 O0 0 3 1 i 4 68 O00000OO00 PSR LW2 OHMM 548992 O0 000 O0 0 3 i 1 4 68 0000000000 ROPE hW2 F/HR 548992 O0 000 O0 0 3 t 1 4 68 0000000000 GR hW9 GAPI 548992 O0 000 O0 0 3 1 1 4 68 0000000000 IS Tape verification Listing chlumberger Alaska Computing Center o~.T. 9~oo.ooo ~.~w: ~..~w:x~.~:o ~?. g~oo.ooo ue~. ~oo.ooo ~. ,~o~ooo ~.~ G~,bU2 9 229 G~.LW2 '1 .,850 ** ENP 0F' DATA ** 3-D~C-1992 07~03 -999.250 PSR.GW2 -999.250 2.580 PSR.LW2 2.243 2.043 PSR.LW2 1.58! !o946 PSR.LW2 !.668 4.175 PSR.LW2 3.557 2,903 PSR,LW2 2,667 2.096 PSR.bW2 2,009 -999.250 PSR,LN2 -999.250 ROPE.LW2 ROPE.LW2 ROpE.bW2 ROPE.LW2 ROPE.LW2 ROPg.bW2 ROPE.LW2 ROPE.LW2 PAGE: 15 32.550 34.361 25.478 52'803 50,420 50,918 -999,250 **** FILE TRAILER **** FILM NAME : EDIT .003 SERVICE : FbICO. VERSION : O01.A.7 DATE ~X REC SIZE ~ ~ 24 FIb~ TYPE J LO LAST FILE **** FILE HEADER **** Flb~ NAME : EDIT .004 FRVICE : rbIC ERSION : O01AO7 DATF ~ 92/],2/ 3 MAX AEC SIZE : 1024 FIL~ TYPE : bO ~RST FILE : FILE NUNBER 4 Tape VerifY, cation Listing chlUmberger Alaska Computing Center 3-DEC-1992 07:03 PAGE: 16 RAW ~WD Curves and log header data for each bit run in separate files, BlT RUN NU~RER~ 3 DEPTH INCREMENT: 0,5000 # FTL~ SUMMARY VENDOR TOOL CODE START DEPTH CDR CDN 9640,0 $ ~OG HEADER DATA DATE LOGGEDI SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRII~LER TD LOGGER(FT): TOP LOG INTERVAL (FT)~ BOTTOM bOG INTERVAL (FT)I BIT ROTATIONAL SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: ~AXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOLTYPE CD~ ''''''''''''' ~ESI&TI'''''''~ TY CDN DENSITY/POROSITY $ # ~OREHObE AND CASING DATA OPEN HOLE BIT SIZE (IN)~ DRILLERS CASING DEPTH ~FT): BOREHOLE CONDITIONS ~UD TYPE: ~UD DENSITY MUD VISCOSITY ~UD PHI ~AXI~UM R~CORDED TEMPERATUREA~EGF): ~UD AT ~AX CIRCULATING TEMPER T ~I.)TRON TOOL ~ATRIX DENSITY: STOP DEPTH 10503,0 2g-OCT-92 FAST 2,3D V4,0 10503 0 10503:0 9640.0 10503.0 TOOL NUMBER mmmmmmmmmmmmmmmmm ~$022 NDSO 18 3 3,0 10,1, 0 ,Tso 55.0 SANDSTONE 2.65 ,IS TaPe Verification Listing ,chlumberger ~lasRa Computing Center 3-DEC-1992 07503 MOLE CORRECTION (IN): TOOL STANDOFF (IN)= FWR FREQUENCY BIT TO RES. 28.g2', BIT TO GR 39.34' BIT TO DEN. 95.75', BIT TO NEUT. WASH DOWN FRO~ 9640' TO 10237'. ' DATA FRO~ DOWNHOLE R~CORDED RATE AT ]0 DOWNHOLE SOFTWARE V4.0C $ # LIS FOR,~T DATA 8,500 PAGE= 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64E~ ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 5 66 6 7 65 9 65 F' 11 66 23 1~ 68 ~3 66 0 14 65 FT 16 66 1 0 66 ** 8ET TYPE - CHIN ** ID ORDER # LOG TYPE CLASS ~OD NUmB SIMP ELE~ CUDE (HEX) DEPT FT 548992 O0 000 O0 0 4 ! ~ 4 68 0000000000 RHOB LW3 G/C3 548992 O0 000 O0 0 4 I 1 4 68 0000000000 DRHO LW3 G/C3 54~992 O0 000 O0 0 4 ! 1 4 68 0000000000 PMF LW3 548992 O0 000 O0 0 4 ! ! 4 68 0000000000 DCAL LW3 IN 548992 O0 000 O0 0 4 1 ~ 4 68 0000000000 IS Tape Verification Listing chlUmbergerAlaska Computl~d Center 3-DEC-! 992 07:03 18 N~P~ $~R N T SE~V ~ APl AP! APl AP! ID ORDER # LOG TYPE CLASS MOD ''''''''''''''''''''''''''''''''''''''''''''''DP.! LW3 PU 5 00 00 0 T~PH L~3 PU 54R992 00 000 O0 0 AT~ LW3 OHM~ 548992 O0 000 O0 0 PSR LW3 OH~M 548992 O0 000 O0 0 ROPE LW3 F/HR 54899~ O0 000 O0 0 G~ LW3 GAP! 548992 O0 000 O0 0 NUMB SA~P ELE~ CODE (HEX) ''''''--'''------------.........'... ~ ~ ~ 4 ~ oooooooooo 4 ! I 4 68 0000000000 4 ! ! 4 68 0000000000 4 1 ! 4 68 0000000000 4 ! ! 4 68 0000000000 DEPT 10503.000 RHOB.LW3 -99g.~50 DCAL'LW3 -999.~50 DPHI.LW3 -999.x50 PS~:LW3 -999.250 ROPE.LW3 18,109 DEpT 10500.000 RHO'B.LW3 -999 250 DCAL:LW3 -999.250 DPHI,LW3 -999:250 P$~.LW3 -999,250 POPE.LW3 18,633 o oo.ooo DCA~.Lw3 0,104 DPMI.LW3 , PS~.LW3 2,187 ROPE.LW3 24.032 DEPT', !0300,000 RHOB'*LW3 2 289 DCAL~LW3 0.022 DPMI.LW3 ~P,:. ,o~oo ooo ~,o~.~w~ ~.~o DC~5.LW3 02!88 DPHI,LW3 0.~6 PSR.LW3 5.429 ROPE,LW3 64.515 ~., ~o~oo.ooo '..o~.~w~ ~.~ DCAL:LW3 0.156 DPHI.LW3 0.! '. Pg~.bW3 ~2.298 ROPE.LW3 68,441 DEPl, 10000,000 RHOB.LW3 ] 022 DC~L.LW3 0,208 DPHI.SW3 P$~,LW'3 0,667 ROPE.LW3 75.157 D~T' 9900,000 RHOB.LW3 DCAL.LW3 0.362 DPHI.LW3 0,040 DCAL:Lw3DEP~ 02~10 DP}!I.LW3 -0.13'2 PSR.LW3 26.475 ROPE.LW3 66o015 DEPT 9700.000 RROB.LW3 2,546 DCAL]LW3 0.185 DPHI.LW3 0.100 PS~.LW3 9.798 ROPE.LW3 67.924 DRHO.LW3 -999.250 PEF.LW3 TNPH.LW3 -999.~50 ATR.LW3 GR.bW3 -999.250 DRHO.LW3 -999.250 PEF.LW3 TNPH.LW3 -999.250 ATR.LW3 GR.LW3 -999.~50 DRHO.LW3 -0. 018 PEF LW3 TNPH,~W3 -999:~50 ATR:LW3 GR.LW3 100.364 DRHO LW3 -0 002 PEF.LW] TNPH:bW3 24:200 ATR..L~ ~..~w~ ~,.~ TNPH.LW3 25,500 ATR: ~ GR.Sw3 33.022 D~HO.hW3 -0 052 PEF 5N3 TNPH.LW3 402100 ATR:LW3 G~,SW3 49.333 DRHO.t, W3 -0.06~ PEF.LW1 TNPH.bW3 33.~00 ATR.LW GR.5'W3 24...399 DR~O.~W3 -0 068 PEF.LW3 GR.BW~ 48 564 DRHO, LW3 -0o~12 PEFoLW3 TNPH:LW3 20. 00 A?R.LW3 GR.LW3 57.321 IS Tape Verification Llstin~ chlumberger Alaska ComputlnO Center 3-DEC'lq92 07:03 PAGE~ 1¸9 2.880 DRHO.LW] O.OiO TEPH.LW3 -999.250 GR.LW3 · 700 45.122 W3 lo8.ooo ,096 ~'N E.D OF DATA **** FILE TRAILER FIL~ NAME ~ EDIT .004 S~RVICE ~ FbIC VERMION : O01A07 D~TE { 92/12/ MAX REC SIZE ~ 1024 FIL~ TYPE : LO LAST FILE **** TAPE TRAILER **** DATE t 92/1~/ 3 O~I~IN : FLIC TAP~ NA,E . , 92641 C~N~I~UATION # : 1 P~.E I US TAPE : CO~NENT { ARCO ADASK4, INC*,POINT MCINTYRE,.PI-20,50-029-22288'O0 **** REEL TRAILER SERVICE NAME ~ EDIT DATE : 92/12/ ORIGIN : ~blC R~EL NAME ~ 92641 CONTINUATION # i PREVIOUS REEL C~M~ENT ' : ARCO ALASKA, INC.,POINT HCINTYRE,P$-20,50-029-22288-O0