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198-032
~ \ ~I BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~~~.;~~~~'~~' :~~`~' .' ~~. ~ ~~Jr=~ ~ ~ bp ~.~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, OCT ~ 5 2009 ~11as~Ca ~ii ~a Gas Cons. Commi~sion Anchorage I ~ g " ~'`32-- ~ ~ ~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad 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 • ~ BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosio~ inhibitor, Sealant Top-off Report of Sundry Operations (10~04) eme L pad 8/13/2009 Well Name PTD # API # Inftial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibftor Corrosion inhibitod sealant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 ~-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29YZ009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 1.-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 1-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 STATE OF ALASKA ALASKA! - .L AND GAS CONSERVATION Cð....JlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612. Anchorage, Alaska 7. KB Elevation (ft): a Repair Well 0 Plug Perforations 0 Stimulate a Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 0 Other 0 Time Extension 4. Current Well Class: a Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 198-032 6. API Number: 50-029-22865-00-00 99519-6612 77.20' 9. Well Name and Number: PBU L-101 8. Property Designation: 10. Field / Pool(s): ADL 028239 Prudhoe Bay Field / Borealis Pool 11. Present well condition summary Total depth: measured 7583 feet true vertical 7019 feet Plugs (measured) None Effective depth: measured 7227 feet Junk (measured) . None true vertical 6667 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2797' 9-5/8" 2827' 2682' 5750 3090 Intermediate Production 7548' 7" 7575' 7011' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7021' - 7188' 6464' - 6629' Tubing Size (size. grade, and measured depth): 3-1/2",9.3# L-80 6895' Packers and SSSV (type and measured depth): 7" x 3-1/2" Baker 'S-3' packer; 7" x 3-1/2" Baker Premier packer; 3-1/2" HES 'X' Nipple 6858'; 6793' 1901' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: " : \ Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run a Daily Report of Well Operations a Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory a Development 0 Service 16. Well Status after proposed work: a Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 N/A Printed Name Terrie Hubble Signature ~12M-1 q. tj, J ~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone 0'8 1,'DU Prepared By Name,Numb&r: Date l' J j., Terrie Hubble, 564-4628 . Submit Original Only AiJb 1 1. ßJU~~ 564-4628 "~lhIN.~ ::- I: .L'L::h~\,;..: '- " d, Well: Field: API: Permit: L-101 Prudhoe Bay Unit 50-029- 22865-00-00 198-032 Accept: Spud: Release: Rig: 07/1 8/04 N/A 07/20/04 Nabors 4ES 07/10/04 DRIFTED W/3.5 BLB & 2.625 G.R., SET PXN PLUG BODY, RAN 3.5 CHECK SET (PIN NOT SHEARED), PULLED PXN PLUG BODY, BRUSHED XN NIP @ 6845' SLM, ATTEMPT TO SET PXN PLUG BODY. PRE-RIG WORK 07/11/04 SET 3.5 PXN PLUG BODY (EQ PORTS. 3 - 3/16" & 1 - 1/8") @ 6845' SLM. RAN 3.5 CHECK SET TO PXN PLUG BODY (PIN SHEARED). SET PXN PRONG (1 3/4 FN , 84.5" OAL) IN PXN PLUG BODY @ 6845' SLM PERFORMED TEST ON PLUG - BLED TUB FROM 800# > 500# (HELD SOLID), SET 3.5 JUNK CATCHER (3.5 G-FN , 123.5" OAL) ON PXN PLUG @ 6837' SLM. 07/15/04 CHEMICAL CUT TUBING AT TOP OF PUP JOINT BETWEEN PACKER AND X-NIPPLE AS PER PROGRAM. RAN TUBING PUNCHER WITH SMALL CHARGES FROM 6820'.6822'. STRING SHOT FROM 6832'-6844'. AND CUT TUBING AT 6840', TWO FEET BELOW X-NIPPLE. ALL DEPTH CORRECTED TO SLB TEMP/JEWELRY LOG DATED 2-APR-98. SEVERING HEAD INDICATES GOOD CUT. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/1 8/2004 7/19/2004 rt BP EXPLORATION Operations Summary Report Page 1 of 2 L-101/NWE1-02 L-101 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/18/2004 Rig Release: 7/20/2004 Rig Number: 4ES Spud Date: 3/7/1998 End: From - To Hours Task Code NPT Phase Description of Operations -_._- 14:00 - 18:00 ' 4.00 MOB P 18:00 - 19:00 I 1.00 RIGU P 19:00 - 21 :00 2,00 RIGU P 21:00-21:30, 0,50 I WHSUR P I 21 :30 - 22:00 I 0,50 KILL P 22:00 - 23:00 1.00 KILL P 23:00 - 00:00 1,00 WHSUR P 00:00 - 01 :00 1.00 WHSUR P 01 :00 - 03:30 ' 2,50 I BOPSUF P 03:30 - 06:00 2,50 BOPSUR P 06:00 - 07:00 1,00, BOPSUF P 07:00 - 07:30 : 0.50 WHSUR P 07:30 - 08:30 1,00 WHSUR P 08:30 - 09:30 1,00 WHSUR P i I 09:30 - 12:30 3,00 I PULL P RDMO of L-1 00. Move to L-1 01. Spot Sub Base, Pipe shed, ,and Pits. PRE I Raise and scope Derrick. PRE Rig up Lines. Spot tiger Tank. Take on 120 deg Sea Waler in 'I Rig Plls. Accept Rig at 19:00 hrs, DECOMP Pick up Lubricator. Pull BPV. Lay down same, DECOMP I Hold PJSM with All. Test Lines to 3,500 psi. DECOMP I' Open Well. Tbg = 0 psi...Annu = 0 psi. Pump down Tbg at 700 psil5 bpm and circulate out diesel Freeze Protecl. DECOMP : Set TWC and tesl. Blow down Lines. DECOMP Nipple down Production Tree, DECOMP Nipple up BOPE. Rig up Test Equipment. DECOMP ,Test BOPE per BP/AOGCC requirements. 250/3500 psi. 1 State's right to wilness test waived by L. Grimalidi. DECOMP Call out DSM to pull TWC. Rig down Tesl Equipment. Pump ¡ out Stack. Blow down Lines. DECOMP I Rig service. DSM arrives on Location. DECOMP Pick-up Lubricator. Pull TWC and lay down same. DECOMP 'Pick-up Landing Joint. BOLDS. Pull Hanger to floor. Hanger broke free at 70K. Tubing pulling free al 64K, Lay down Landing Joint and Hanger. DECOMP : POOH/Tally standing back in Dernck with 216 Jts 3 1/2" 9,3 Ibift L-80 Tbg, 2 ea X-Nipples, 3 ea GLMs w/PuP Jts, and a 2,25" Chemical Cut Stub. Chem Cut was clean, Tubing is in , good condition. Note: The E-Line Tubing Punch Gun i performed poorly. No penetration...just dents. DECOMP Clear and clean floor. Make up Dress-Off BHA as follows: 6" x 3 1/2" Shoe, Extention, Drive Sub, XO, XO, 2 ea Boot Baskets, ; Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, XO, DECOMP TIH with BHA #1 and 218 jls 31/2" Tubing. PUW = 68K...SOW = 58K, Pick-up Kelly. Bring Pump on line at 5 bpm/400 psi. Tag top of 3 1/2" Chemical Cut Stump at 6,842' '4es KB, DECOMP Reverse circulate. Pump Hi-Vis sweep around, 5 BPM @ 500 psi. DECOMP Blow down & sland back kelly. LID 17 its of 3 1/2" DP. DECOMP POOH & stand back 67 stands of 31/2" DP. DECOMP i LID BHA. Clear & clean rig floor. Prepare to run 3 1/2" completion. Load pipe shed & Layout assys in running order. RUNCMP Hold PJSM & review completion running procedure. RUNCMP RIH w/ 3 1/2" completion. Tag up @ 6843', M/U head pin & break circulation, Tag up @ 6843 & pressure increased 100 I psi. SId pump & swallow 6' to 6849'. P/U 2' & measure up. I RUNCMP : Space out w/4 pups. total of 21.21'. ( 10.60', + 4,18', + 4.11', + , 2.32') M/U hanger & landing jt. & R/U lo circulate, RUNCMP Reverse circulate well. Pump 100 Bbls of 120 Degree seawater & follow w/180 Bbls of 120 degree inhibited seawater. 3 BPM @ 250 psi. RUNCMP ! Circulate down over stub w/ completion string & pressure ; increased 100 psi when swallowing stub, Land completion. RILDS. Drop ball/rod. UD landing jt. Pressure test lines. RUNCMP pressure up to 4000 psi & set packer. Test for 30 min. bleed off tbg to 1500 psi. pressure up on annulus to 3500 psi & test for PRE 12:30 - 14:00 1.50 FISH P 14:00 - 17:00 3.00 FISH P , 17:00 - 18:00 1.00 FISH P 18:00 - 19:30 1.50 FISH P 19:30 - 22:30 3.00 FISH P 22:30 - 00:00 1.50 FISH P 7/20/2004 00:00 - 00:30 0.50 RUNCOMP 00:30 - 05:00 4.50 RUNCOMP 05:00 - 06:00 1.00 RUNCOMP 06:00 - 08:00 2.00 RUNCOMP 08:00 - 09:00 1.00 RUNCOMP 09:00 - 10:30 1.50 RUNCOMP PMI,,",j -;"27'200J 10'4323 AI'..1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( Page 2 of 2 BP EXPLORATION Operations Summary Report L-1 01 INWE1-02 L-101 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours Task Code NPT Phase ------- 7/20/2004 109:00 - 10:30 1.50 RUNCOMP RUNCMP 0.50 BOPSUF P RUNCMP '10:30 - 11:00 ! 11 :00 - 12:00 1.00 BOPSUF P RUNCMP 12:00 - 14:30 2.50 WHSUR P RUNCMP 14:30 - 16:30 2.00 WHSUR P RUNCMP 16:30 - 17:30 1.00 WHSUR P : RUNCMP 17:30 - 18:00 0.50 DEMOB P POST Start: 7/18/2004 Rig Release: 7/20/2004 Rig Number: 4ES Spud Date: 3n /1998 End: Description of Operations --- 30 min. Bleed off tbg& shear DCR valvre. Pump down both sides & check shear. 3 BPM @ 400 psi. Charted entire test. Pump out BOP stack. Se1 TWC & test to 1000 psi. R/D & blow down lines, N/D BOPE. N/u X-mas tree & test tree & void to 5000 psi. Wait on DSM to pull TWC. Pull TWC & pump Freeze protect well w/ diesel. 3 BPM @ 500 pSI. Allow diesel to U-tube & equalize, Secure well. Clean cellar. RELEASE RIG @ 1800 hrs. P"nt""j :' 1:' 200.1 10..n'23 AI'.1 ~ TREE = 4 1" õ" ~M CWV \JIÆll HEA 0 = 13-5,S" FMC '_n_~_--._.'---_--r---~- - A.CTUA. TOR = BAKER ------'---- KB El E'~' " n 20' ------ - --_. - .--.--- SF, ELEV " ~O 40' 'ji"Òp ~ - iiA 0-. . .._. .u." ----. ---- .-.~~ . -~-~.~~g_lc_~ ---- -----.~, [)]tum MG " j'~3:' -_...-.-_._._--.~-- ~-_... 1 D3tum T'VD = 6600' 35 L-101 r--- l SAFETY NOTES: . -------'--- FORMERLY NWE 1-02 - '~--". .---- _.~ - ---J-f -- --- - ----. -----1 i 9.:;,8' (~5(; ..,.tI l-!!ú STR.S.- iD= B1381_'li 2827 ~ l ~ \ - ~ . ! jMiñimüm 10 :: 2.7501 @ 6883' 1 l3-1.12" HES XN NIPPLE j J -,---.._L_- L l____i T:~:~, ,~_-~~~~i~~~~' ~~~:.~~j~-~~~~:~:ï:: :~~¡ ¡ ¡ i r - ~ I L ¡ ~~ I (__h______-- h] r---- --- -- - - -- on --------------, - --_..--- ¡ ! ¡, ,:.,:- \--- - i , i' ~ -"~\W""---1" ¡""""""""-''''''-'o.''''''-'-='''''''='''''''''';'"",",''....d--- ---, -. 1 .¡~~ Z;:. ! - ~-~~' - ..:'~~:::~~:_~~.~~,';'_.ì--;'~~( 1(,_= -'?;;;- ." ~ ¡ r 6883'-1--F~:-.~-,.r:--;-',-¡:,;p-,è;;--'~.1 f)8Q4' I. _r . I ' ., "'--'--=--.-'--. - - ~ , ... - J; " --r-'--'¡ i J L : -,-' ... 'I ",',. r.,,\,'; ,-, 11)'U,,"11" 1 ;;. ~ '~" .~: I -,:!'''~~;:: '.:, ;'~:;~:. I ~:~'; , ~,'~;:,~~,";; ! l ¡ .' \ ',., . - " ,. ! . - .", ., , -11 . ! Tl .- .. " .: ¡ '-",. ,>:. ! '.-' jU"~'::."; ! -'j \ ! Y r---,---c------ ,---------- i ~ u.. 'm-:---¡-- , r¡',¡'~I ., ",,- -'.' t " , /':"1.'/ II , .I~~~~~- ~--_.-----a~~EALsl:'~~~._~-~- ~ " -;").,--3' "'t,"-., ._",'I'¡f"I1--t.c.-I,,,,,¡ ~1 I p' ['¡":;'''I"¡,~--,,,-,'\.I:',I!'''(J...~.;J£Cn N' ",'.--" 1"-,,,, ::~~~~-~-~~~~-~- i.. L ":' -----... --.,-.-... .. :-...,,"..:..':':- ":''::'==.'''':' '"':-:_'""':'" .:"'_"--.-.~=~.- :_~.. ~ :-:"-.~; ':""'~.:-"':.~ . - .. . ----. ..- -.~I .- .:... ~ ¡ ~_.. ......... _..- " ..-":: ~ ;~'. -:".. .:: .. ":."':: ::: ~'.':':"'."!':""- --:-=..-_...~"':".: _'"'::t..--- ":"_~:"-~~'_"'::~'::. ".:;-':-: "; - ~ .1~~:!=::_."..". :::.:. .'::::" - ~~.: ~... ":':=--:.::"'_- "::'_--":.".:":"'::-:_'''':':':::''':-~~.:''' .:".. ..' ~,.:.. - .. !'~ ..=:.!:~~- "',,":'":"':" _:-.:-::.~ 48 2 2~ -. . -l.-t ~:: - :::~._:~:-:.::~:_~ir ,~: i." (?;c ~:- è:, L L --\ ,1- : l}-I i " , I ¡ i''''~ ----~---L. :_._-_.:__.__._--~~---~---~,_J [-~----_.- -l-'L_~._~ -~-_:~~-- .-- - ----] J- {=:-~ -. .""-' -: ----, -1 . -.. "__0__._- _0.____- -_.--......J . ~;~'~ .~. ;:'~-; .,',; "J--J 68g6-'--l-1-~.. - :,' ~.~.. ~--j . 6887~.~____!'- i~~, :'~¡:'-_:-::'--' ~-~'~::::---~:~~~~!.2~'I,~: '] STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ FIRST PROD FIRST PRODUCTION REPORT Pull tubing _ Alter casing _ Repair well _ Other _X REPORT 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 2766' FNL, 3917' FEL, Sec. 34, T12N, RllE, UM At top of productive interval 2766' FNL, 2212' FEL, Sec. 34, T12N, R11E, UM At effective depth 890' FNL, 2191' FEL, Sec. 34, T12N, R11E, UM At total depth 835' FNL, 2139' FEL, Sec. 34, T12N, RllE, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic_ Service__ (asp's 582997, 5978233) (asp's 584678, 5980118) (asp's 584698, 5980128) (asp's 584750, 5980183) 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-101 9. Permit number / approval number 198-032 10. APl number 50-029-22865 11. Field / Pool Prudhoe Bay Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 7583 feet Plugs (measured) 7019 feet Effective depth: measured 7112 feet Junk (measured) true vertical 6554 feet Tagged TD @ 7112' (10/24/2001) Casing Length Size Cemented Measured Depth Conductor 110' 20" 260 sx Arctic Set (Approx 140' Surface 2797' 9-5/8" 349 sx 'G', 1029 sx CS 2827' III, 44 sx 'G' Production 7548' 7" 490 sx Class 'G' 7575' True Vertical Depth 140' 2605' 6934' Perforation depth: measured Open Perfs 7021' - 7048', 7052' - 7064', 7079.5' - 7085.5', Open Perfs covered w/fill 7168' - 7188'. true vertical Open Perfs 6464' - 6491', 6495' - 6507', 6522' - 6528', Open Perfs covered w/fill 6609' - 6629'. Tubing (size, grade, and measured depth) 3-1/2" 9.2#, L-80 to 6858'. Tubing Tail @ 6896'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 6858'. 3-1/2" HES 'X' Nipple @ 499'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 11/11/2001 11/15/01 OiI-Bbl well shut-in 4258 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Frist Day of Production was 11/12/2001 2026 42 16. Status of well classification as: Oil __X Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Bruce W. Smith ,,*-~'- ~ tj.l,~r~ , Casing Pressure Tubing Pressure GL Service Title: Borealis Development Petroleum Engineer Date December 18, 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 11/12/2001 11/15/2001 12/1 2/2001 L-101 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FIRST DAY OF PRODUCTION PRODUCTION DATA DRILL-POST WORK: DRIFT-SET K-VALVE (POST FRAC) 11/12/2001 11/15/2001 12/12/2001 EVENT SUMMARY FIRST DAY OF PRODUCTION PRODUCTION RESULTS --- OIL - 4258 STB, WATER - 42, GAS - 2026 WELL HEAD PRESSURE NOT REPORTED AND WELL IS ON GAS LIFT. DRIFTED THROUGH SVN WITH 2.80" GAUGE RING. SET 3 1/2" K-VALVE (EQL DEV - 227 DOME). RAN 3 1/2" CHECK-SET. BROUGHT WELL ON. NOTIFIED FLUIDS PUMPED BBLS 0 NO FLUIDS PUMPED 0 TOTAL Page I bp BP Exploration (Alaska) Inc. 900 East Benson Blvd PO Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 November 05, 2001 Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska, 99501 Re: L-101 Prudhoe Bay Field / Borealis Pool Dear Mr. Maunder, Well L-101 was perforated and fraced without the Form 10-403 being submitted to the AOGCC before the work was done. This was an over slight on my part. I have completed and included the Form 10-404 that details the work that was done on this well. Please accept my apology for not submitting the 10-403 on time. I will do better in the future. Sincerely, DeWayne R. Schnorr Technical Assistant STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X ADPERFS / FRAC Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2766' FNL, 3917' FEL, Sec. 34, T12N, R11E, UM At top of productive interval 2766' FNL, 2212' FEL, Sec. 34, T12N, RllE, UM At effective depth 890' FNL, 2191' FEL, Sec. 34, T12N, RllE, UM At total depth 835' FNL, 2139' FEL, Sec. 34, T12N, RllE, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 582997, 5978233) (asp's 584678, 5980118) (asp's 584698, 5980128) (asp's 584750, 5980183) 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-101 9. Permit number / approval number 198-032 10. APl number 50-029-22865 11. Field / Pool Prudhoe Bay Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2797' Production 7548' 7583 feet Plugs (measured) 7019 feet 7112 feet Junk (measured) 6554 feet Tagged TD @ 7112' (10/24/2001) Size Cemented Measured Depth 20" 260 sx Arctic Set (Approx 140' 9-5/8" 349 sx 'G', 1029 sx CS 2827' III, 44 sx 'G' 7" 490 sx Class 'G' 7575' True Vertical Depth 140' 2605' 6934' Perforation depth: measured Open Perfs 7021' - 7048', 7052' - 7064', 7079.5' - 7085.5', Open Perfs covered w/fill 7168' - 7188'. true vertical Open Perfs 6464' - 6491', 6495' - 6507', 6522' - 6528', Open Perfs covered w/fill 6609' - 6629'. Tubing (size, grade, and measured depth) 3-1/2" 9.2#, L-80 to 6858'. Tubing Tail @ 6896'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 6858'. 3-1/2" HES 'X' Nipple @ 499'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl well shut-in well shut-in Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify t/b~t the foregoing is tru~ct to the best of my knowledge. Title: Borealis Development Petroleum Engineer Bruce W. Smith Date November 05, 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 08/26/2001 09/28/2001 09/28/2001 09/29/2001 09/29/2001 09/30/2001 10/01/2001 10/06/2001 10/07/2001 10/08/2001 10/08/2001 10/11/2001 10/16/2001 10/18/2001 10/19/2001 10/24/2001 08/26/01 L-101 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DRILL-POST WORK: ROTATE TREE'S FOR PRODUCTION DRILL-POST WORK: PULL 3.5" XX & XN PLUG/DRIFT TO TD W/2.5" DG/SBHPS W/MRT(PRE-FRAC) DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: PRE-FRAC DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: DRILL-POST WORK: SBHPS ( PETREDAT ) W/MRT PRE FRAC SANDBACK TAG SAND, DUMP BAIL LIQUID LATEX ON SAND DUMP BAIL 20/40 FRAC SAND / LATEX CAP DUMP BAIL 20/40 FRAC SAND SANDBACK D &T / DUMP BAIL LATEX / SET SPMG (IN PROGRESS) SET SPMG / MITIA (PRE-FRAC) BHT & JEWELRY LOG / PEFORATION HYDRAULIC FRAC TREATMENT KUPARUK "C" FCO DFF - SET GLV'S (POST FRAC)- IN PROGRESS DRIFT / SET GLVS SBHPS W/MRT EVENT SUMMARY SET BPV, ROTATE TREE'S PER PRODUCTION/NORCON REQUEST, PULL BPV 09/28/01 09/28/01 09/29/01 EQUALIZE AND PULL 3.5" XX PLUG @ 478' SLM. EQUALIZE & PULL 3.5" XXN PLUG @ 6870' SLM. DRIFT TBG W/2.5" DG. LOCATE TTL @ 6881' SLM + 6' - 6887' ELM. TAG TD @ 7453' ELM (265' RH). RDMO SBHPS ( PETREDAT ) W/MRT. MRT SHOWS 156 DEGREES. GOOD DATA. WELL BUILDING PRESSURE @ 2 PSI/HR. RDMO. RIH W/CHOKE CLOSED. FORMATION ACTING TIGHT. LET WHP BLEED, TAG TD, CORRECT TO 7053' SLM (8' CORRECTION), PUMP 7300# FIRST STAGE, 22 BBLS RIVER SAND SLURRY. TAG TOP @ 7155' CTD. PUMP 1700# SECOND STAGE, 7 BBLS. TAG SAND TOP @ 7076' CTD. CIRC WELL TO CLEAN 2%KCL. FP WITH 22 BBLS 50/50 MW. INJECTIVlTY TEST - LESS THAN 0.5 BBLS TO PRESSURE FROM 400 TO 1000 PSI. LOST 320 PSI IN FIRST 5 MINS. LOST TOTAL OF 400 PSI IN 15MINS. WHP STABILZED. ***LEFT WELL SI & FP**** 09/29/01 RIH W/2.70 CENT., TEL W SAMPLE BAILER TO TT @ 6872' WLM, TD @ 7069' WLM (CORRECTED TD @ 7084') -- Page 1 09/30/10 L-101 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DUMP BAIL 20/40 FRAC SAND. THE SAND LEVEL WAS FOUND TO BE TRAVELING UP HOLE BY MORE THAN WHAT OUR BAILERS WERE DUMPING. SAND TOP RISES EVERY TIME WE OPEN THE LUBRICATOR. NEED TO MAINTAIN WELLHEAD PRESSURE OR ELSE THE SAND LEVEL RISES. LAST SAND TOP TAG BEFORE MIDNIGHT WAS AT 7078' CORR. WELLHEAD PRESSURE IS BEING MAINTAINED AT 1000 PSI. JOB IN PROGRESS. 10/01/01 10/06/01 10/07/01 10/08/01 10/0 8/01 10/11/01 DUMP BAIL 20/40 FRAC SAND W/10' 2.50" DUMP BAILER, DEPTH OF 7065' WLMD. -- MAKE TWO MORE DUMPS OF SAME -- CHECK DEPTH W/TEL & 2.7 GR, 7065' WLMD, 7078' CD. SAME DEPTH- NO CHANGE. -- RDMO, RETURN WELL TO OPERATOR SHUT IN RIH W/2.25" REV NOZZLE, TAG AND CORRECT TO LAST SLICKLINE TAG AT 7078'. LAY IN 500# OF 20/40 RIVER SAND. WAIT AND TAG @ 7085'. PRESSURE TEST PLUG: 0.2 BPM AT 1600 WHP. REVERSE PLUG TO 7070. DRY TAG @ 7068'. POOH AND FREEZE PROTECT WELLBORE TO 2500' W/ 6O/4O MEOH. TAG TD W/2.6" CENT @ 7072' MD (WINDOW BETWEEN 7068' TO 7075' MD). MADE THREE LAYTEX DUMP BAIL RUNS W/2.5" X 10' BAILER. MIT TBG/LAYTEX CAP TO 3525 PSI --- PASSED. SET 3 1/2" WHIDDON C-SUB. PULLED STA# 1 RK-DGLV. SET STA# 1 RK-SPMG (HES). MITIA TO 3500 PSI---PASSED. PULLED C-SUB. RDMO. LEFT WELL SHUT-IN. COMPLETED TEMP/JEWELRY LOG AND PERFORATION. TAGGED TD @ 7064 FT. MAX BHT 153 DEG. MADE TWO GUN RUNS 2.5" HSD 2506 PF, 6 SPF, 60 DEG PHASING. SHOT INTERVALS: 7021-7048 FT & 7052- 7064 FT. TBG FLUID LEVEL @ SURFACE AFTER BOTH SHOTS. TBG PRESSURE BUILT UP DURING INITIAL GUN RUN AND WAS CONTINUALLY BLED OFF WHILE RIH; PRESSURE DID NOT INCREASE AFTER EITHER SHOT. DATA FRAC W/50 BBLS YF125LG FLUID. DISPLACE TO PERFS @ 5 BPM, INC RT TO 25 BPM. FLUSH W/64 BBL 2% KCL. ISIP=1891 PSI. EST. CLOSURE @ 13.1 MIN, 74% FLUID EFF., CLOSURE PS1=1495 PSI. RE-DESIGN FRAC. PUMP 30 BBL YF125LG PAD @ 25 BPM. START 1 TO 6 PPA RAMP (1 PPA 24/40 C-LITE 1300#. 2-6 PPA 16/20 C-LITE). STEP 6 TO 10 PPA STAGES IN 1 PPA STEPS. FLUSHED W/60 BBLS LAST 13 BBLS DIESEL (1500' FP). ISIP: 5223 PSI. AVE PSI=4700 PSI. PLACED 188,264# PROP BEHIND PIPE. LEFT 3389# IN PIPE. EST TOP OF SAND SLURRY=6896'. ALL CUPS LEFT ON TREESAVER. Page 2 L-101 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/16/01 MIRU DS CTU ¢8, RIH W/2.25" JSN, TAG UP ON ICE AT 698' CTD, COME ON- LINE PUMPING 2% XS KCL, WORK THROUGH ICE, CO TO 7227' CTD, POOH CHASING RETURNS 80%. WELL STARTED TO COME ON, COMPROMISING FP FROM 3000', BULLHEAD 26 BBLS MW TO ENSURE FP. ***LEFT WELL SI & FP, TURNED OVER TO PAD OP*** 10/18/01 DRIFTED WITH 2.50" CENT/SB TO TD @ 7114' WLM (- 77' RATHOLE) RECOVERED SAMPLE OF FRAC SAND. SET C-SUB. PULLED SPMG FROM STA ¢1 - 6802' SLM. IN PROGRESS. 10/19/01 PULL 1-1/2" DGLV'S FROM STA'S ¢ 2 - 5438' & ¢ 3 - 3205' SLM. SET DGLV IN STA¢ 1 - 6802' SLM, SET LGLV IN STA ¢ 2 & OGLV IN STA ¢ 3. (ALL VLV'S HAVE RK LATCHES) PULL CATCHER SUB, NOTIFY PAD OPER OF WELL STATUS. WELL LEFT SHUT IN. 10/24/01 SBHPS W/MRT ( PETREDAT ) TAGGED TD @ 7112' CORRECTED. PRESSURE @ 6400 TVD (BTM MOST STOP) 3380 / TEMP 150 DEG. MRT TEMP 148 DEG. *** LEAVE WELL SI*** FLUIDS PUMPED BBLS 7 PRESSURE TEST LUBRICATOR TO 3000 PSI W/1 BBL OF DIESEL (7 TESTS) 5 METHANOL WATER 55 50/50 METHANOL WATER 106 60/40 METHANOL WATER 975 2% KCL WATER 137 KCL WATER WITH FRICTION REDUCER 206 2% EXTRA SLICK KCL WATER 20 1.5¢ BIO 17 CLEAN GEL 29 6.5 PPA SAND SLURRY 1557 TOTAL ADD PERFS 1 O/O8/2OO 1 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2.5" HSD 2506 PF, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 7021' - 7048' 7052' - 7064' Page 3 ALASKA OIL AND GAS CONSERVATION CO~DII~SIO~ TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 October 4, 2001 Gordon Pospisil, Team Leader BP Exploration (Alaska) Inc. West End New Developments PO Box 196612 Anchorage AK 99519 Re: Wells NWE 1-0lA, NWE 1-02 and NWE 2-01 Dear Mr. Pospisil: Enclosed please find 3 Applications for Sundry Approval to extend operation shutdown for each of the above referenced wells until April 2002 that we are returning to you because the current status of each of these wells makes these sundry applications unnecessary. Well Completion Reports have been filed for wells NWE 1-0lA and NWE 1-02. Therefore, the status for those two wells is shut-in and they should be included with the shut in wells list required by 20 AAC 25.115. A Well Completion Report has also been filed for Well NWE 2-01. Our records also reflect that the well has a downhole cement plug covering the reservoir interval and extending up in to the casing. The well is filled with 9.6ppg mud to the base of permafrost and has diesel freeze protection to surface. Our records reflect that the well has never been flow tested and is not in pressure communication with the reservoir. Although the well does not have a near surface plug as required by 20 AAC 25.110(d), the well condition satisfies the requirements of 20 AAC 25.112(i) because it provides for at least equally effective prevention of fluid movement into sources of hydrocarbons or freshwater. The Commission will, therefore consider the well suspended. If you have any additional questions, please contact Tom Maunder or Bob Crandall at the above telephone number. Sincerely, Cammy O~chsli Taylor Chair bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Auto. st 22, 2001 Commissioner Julie Heusser Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 994501 Re: Well Re-Naming Dear Commissioner Heusser: The operator request the following Prudhoe Bay Satellite Wells be re-named as follows: AP1 Number Permit Number Old name New Name 50-029-22865-00 98-32 Sincerely, Bruce W. Smith Development Engineer, GPB-WEND BWS:bws CC: Well File Mark Evans (Exxon) Jim Johnson (Phillips) Wade Fennel (Chevron) K. Griffin (Forest) S. Copeland (MB-2) G Anc PDC NWE 1-02 L- 101 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ NAME CHANGE Pull tubing _ Alter casing _ Repair well _ Other_× NAME CHANGE 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 2513' FSL, 3918' FEL, Sec. 34, T12N, R11E, UM At top of productive interval 4379' FSL, 2212' FEL, Sec. 34, T12N, R11E, UM At effective depth (n/a) At total depth 4447' FSL, 2150' FEL, Sec. 34, T12N, R11E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-101 (NWE1-02) 9. Permitnumber/approvalnumber 098-032 10. APInumber 50-029-22865 11. Field / Pool Prudhoe Bay Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 7583 feet 7019 feet Effective depth: measured 7488 feet true vertical 6925 feet Plugs (measured) Casing Length Conductor 110' Surface 2797' Intermediate 7548' Liner Junk (measured) Size Cemented 20" x 30" 260 sx Arctic Set (Approx 349 sx 'G', 1029 sx CS 9-5/8" III, 44 sx 'G' 7" 490 sx Class 'G' Perforation depth: measured Kuparuk C1 7168'- 7188' Kuparuk C3 7079.5' - 7085.5' true vertical 6532' - 6552', 6543' - 6451' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 6895' MD. Packers & SSSV (type & measured depth) 7" Baker S-3 @ 6858' MD Measured Depth True Vertical Depth 110' 110' 2827' 2605' 7575' 6934' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoi,,ng is true and correct to the best of my knowledge. ~ ~ Title: Development Engineer Bruce W. Smith Date August 22, 2001 Prepared by Bruce Smith 564-5093 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 9.3 #/tt, L-80, 8 rd, EUE, Mod Tubing. ID = 2.992', Capacity = 0.008706 bbis.,Tt wil~ 61 Bbls cement 9-5/8", 47#/It, L-80, Btrs A/B Mod JOementing Stage Collar with l~5 BbLs cement ' J O KB Eiev '-77.2' BFE~w =50.4' GL Elev Ice Pad E~ev ~ 46.8' JHE 1/2' 'X' Nipple, S, 2.813" ID __ Gas Lift Mandrels With Dummles · Ca.mco~ KBG-2-LS~ 1.5" Pocket oo ~L~.~j :~_._~ - I I :215,,~3' II P__erforation Summar~ REF LOG: BHC/GR (xx/xx/xx) __SIZF RPF INTFRVA! ISTATi!S ' 2-1/2" 8 7168- 7t88 Open -- Frac'd 2-1/2' 4 7079.5 - 7085.5 Open Frac'd __ ~Open I Sqz'd 7079.5 - 7085.5' Perfs Peals 'X" Nipple ~ :2.813' ID 7" Baker "S-3" Packer -- 3.875" ID ~ 3-1/2', 'XN'; Nipple I r3' ID, 2.75" NoGo ~ WLEG [6,896,~ 7168 - 7188' Frac Proppant 26#/ft, L-80, Btm A/t3 Mod Cemented with 50 Bbls Date ~ IMI [ ? Shut Down Of O rations Corriments j-'--------------=~ ---'---'-- North West Eileen WELL: NWE 1~-~' __ ~API No: 50-029-22865 ,Sec. :~4~ T12N1 R11E J BP Exploration (Alaska) bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 1, 2001 Commissioner Julie Heusser Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 994501 Re: Extension of Operation Shutdown NWE 1-02, Prudhoe Bay Field Dear Commissioner Heusser: Please find the attached request (Form 10-403 Application for Sundry Approval) to extend operation shutdown for well NWE 1-02 until April 2002. The request is submitted in accordance with the requirements of 20 AAC 25.072. If you need additional information, please contact Bruce W. Smith at 564-5093. NWE 1-02 is an appraisal well drilled from an ice pad, shared with well NWE 1-0la, located in T12NR11E section 34, in the western portion of the Prudhoe Bay Unit in early 1998. The well was left in a mechanically safe condition which would allow us either to resume further testing or to complete the well for development operations. One year operation shutdown was approved in June 1998, extended in May 1999 and February 2000. Since the drilling of this well, the owners have made progress in evaluating the drilling results and in the potential development for the area. The owners are currently engaged in a conceptual engineering effort to better define pad and pipeline requirements for the area. Gravel has been laid out to this well and NWE 1-0la. The gravel road will allow drilling and testing year-round, not just during winter ice season. Extension of the operations shutdown for NWE 1-02 will preserve additional appraisal, testing and/or development options at this location. Sincerely, Gordon Pospisil, Team Leader West End New Developments GP/bws Enclosures (3) Cc: Bruce W. Smith RECEIVED ~aR 1 ~ 2001 Alaska 0il & Gas Cons. Commission Anchorage O¢IGILfAL STATE OF ALASKA ALASKA:_ ,L AND GAS CONSERVATION CC,..~vllSSlON APPLICATION FOR SUNDRY APPROVAL Type of Request: I% Abandon [] Suspend [] Plugging [] Time Extension [] Perforate I~ Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other ~ Change Approved Program [~ Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2513' NSL, 3918' WEL, SEC. 34, T12N, R11E, UM At top of productive interval 4379' NSL, 2212' WEL, SEC. 34, T12N, R11 E, UM At effective depth At total depth 4447' NSL, 2150' WEL, SEC. 34, T12N, R11E, UM 12. Present well condition summary Total depth: measured 7583 feet true vertical 7019 feet Effective depth: measured 7488 feet true vertical 6925 feet Casing Length Size 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Plugs (measured) Junk (measured) 6. Datum Elevation,CF or KB) KB?= 77.2O 7. Unit or Prop, C'rty Name Prudhoe/~fy Unit 8. Well I~mber // NWE 1-02 9. ,~_~2it Number I~. APl Number / 50- 029-22865 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Structural Conductor 110' 20" 260 sx Arctic ,) Surface 2797' 9 5/8" 349 sx 'G', II, 44 sx 'G' Linerlntermediatepr°ducti°n 7548' 7" 490 sx ~~~? 0'/ 110' 2827' 7575' TVD 110' 2605' 6934' / Perforation depth: measured Kuparuk C1 7168',- 7,/f88', Kuparuk C3 7080' -/,¢086 true vertical 6532' - 6552', 6~/~'- 6451' M,~R I 2 Z001 Tubing (size, grade, and measured depth) 3 1~", 9.3#, L-80 to 6895' MD Alaska Oil & Gas Cons. Commission Packers and SSSV (type and measured dy 7" Baker S-3 @ 6858' MD Anchorage / 13. Attachments [] Description summaw//Sf proposal [] Detailed operations program [] BOP sketch / 14. Estimated date for commencing ope/Orion 15. Status of well classifications as: April 01,2001 to Ape 01,2002 16 If r [] O~1 [] Gas [] Suspended . p oposal was verbally approve/~/ ' Se~ice Name of approver / Date approved Contact Engineer Name/Number: /Bruce W. Smith 564-5093 Prepared By Name/Number: Scott La Voie, 564-4636 17. I hereby''~'~tif'y 'that the f/Cegoing is/trUe and correct to the best of my knowledge ' Signed t-,~-~-~..~ ~v~ //.,~.,~"~ /' ~ - Title Senior Petroleum Engineer Date Commission Use Only Conditions of Approv/~l: Notify Commission so representative may witness Approval No. Plug integrity__ BOP Test __ Location clearance ~ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 ORIGINAL. Submit In Triplicate NWE 1-02 Sundry Status: Operation Shutdown Original Date of Sundry Approval: 6/19/98 Time extension approved 5/6/99 and 2/10/00. Post Drilling Status: Well is fully drilled, cased and cemented. · Well has 26 ft of perforations in the casing (7079.5-7085.5, 7168-7188 MD). · A complete wellhead and Christmas tree is in place, tested and operational. A backpressure valve has been set and tested in the wellhead receptacle. The wellhead and Christmas tree were tested to 5000 psi. · Well has 6896 ft of 3 V2" 9.3#, L-80 tubing, stung into a packer at 6858 MD. The tubing was tested to 4000 psi. · The Tubing string has two (2) wireline set plugs in place at 6883 and 499 ft MD. · The Inner Annulus (3 V2 x 7" casing) was pressure tested to 3500 psi. · The Inner Annulus is freeze protected with 2000 ft of diesel over 8.6-ppg seawater. · The well contains 2300 ft of diesel over 8.6-ppg seawater between 2000 - 5800 ft MD. The remaining tubing and casing across the perforation has wellbore fluids present. · All Gas lift mandrels have been dummied off. · The well has had 2 fracture stimulations in the Kuparuk C 1 and C3 sands. · Prior to setting wireline plugs, the well was capable of flowing 100-200 BOPD. · The Kuparuk C-4, which is the primary target zone, has not been perforated. Current Status: Gravel Pad has been built around the NWE 1-01 a and NWE 1-02 wellheads, new pad has the designation of L-Pad. Well is being observed on a regular basis. Borealis Field is being developed in the Kuparuk Formation. Request: Extend Shut Down of Operation Status to April 2002. Tentative Plans: Continue monitoring. Log Borealis Field wells in the Kuparuk Formation for reservoir evaluation. Review and update well plans with AOGCC by April 2002. Alaska Oil & Gas Cons. CommisSion Anchorage NWE 1-02 GL E]ev ,:=44..? Ice Pad Elev. 46.3' vlM", 9.3 #/tt, L-80, 8 rd, EUF_., od Tubing. lID ,-- 2.992', Capacity = 0.008706 bi)Is/it nulus with 51 Bbls cement I9-5/'8', 47#/Tt, I L-80, Btrs A./B Mod 5 C5~Ben§ng Stage Collar with bls cement ' Perforation Summary REF LOG: BHC/GR (xx/xx/xx) $1ZF SPF INTERVAL 'STATUS 2-1/2' 8 7168- 7188 Open Frac'd 2-1/2' 4 7079.5 - 7085.5 Open Frac'd _ [ Open I ,Sqz'd 7079.5 - 7085.5' Peds Peds 3-HEI/2" 'X' Nipple, 7', 26#/tt. L-80, Btm A/B Mod Cemented with 50 Bbls Date 4/17/98 · Gas Uft Mandrels With Dummies _ Camco, KBG.2-LSt 1.5' Pocket 3I 3.220I 2I s,4~3' I ' I ~,~18' I ~-~/2','~ Nipp~ 16,846'1 2.813' ID 7' Baker "S-3" Packer 3.875' ID 'XN'; Nipple 2.813' ID, 2.75" NoGo WLEG i 6.896, I I ! I , I I I i Well Compliance Report File on Left side of folder 198-032-0 ..// u )'07 83 xw :019 BP EXPLORATION Current: PRUDHOE BAY UN NWE 01-02 50- 029-22865-00 ~/mompletion Date: 4/2/98 Completed Status: 1-OIL T Name CMR CMR-RAW L CMR/FMI COMBO MUD DS1 L ENG LOG L FMI-RAW L FMS W/DIPS PERF [, PERF L PERF L PEX-AIT L PEX-CN/GR L PEX-SSTVD PEXONDT L RFT TEM P/JWL L USIT R ADT WELL SUMRY R DIPMTR EVAL R MMS DIR R MMS SRVY R RIFT R SONIC EVAL R SRVY RPT R WELL SMMRY T 8506 Interval 6900-7588 OH ~J:i'~qAL 6900-7580 OH 5 (C) 6900-7575 OH & ...... SPERRY 110-7583 OH 1 ~NAL 2824-7548 OH t//. SPERRY 110-7583 OH 1 ~AL 6800-7580 OH 1 BL(C) 6765-7480 OH AL 6750-7300' :'~ CH 5 / ~.,~..,t~ ~? -'~INAL 6800-7580 CH 5 ,,,'.7 ~AL 6800-7072 -7 2~..~ '~ CH 5 ~AL 2824-7574 OH ~AL 2824-7574 OH ~L 2824-7574 OH ~kAL 2824-7574 OH ~INAL 3027-7368 OH 6800-7480 ~/~/~ CH 5 ~AL BL(C) 2823-7476 ~/~/~ CH 5 ~NAL SPERRY (C) ENG LG & EWR OH ~¢S'dHLUM 7544-7551 OH ~;'~i}bCM 0-7450 ':3.;? :J:" .,.:'x: ,'}' ,.'"(.~(,. OH ~RY 0-2728.40 OH ~i'LU M 5920-6215 OH ~(C) 2800-7550 OH ~'HLUM 116.49-7505.95 OH ~RRY W/MUD & DIR SRVY OH SCHLUM PEX-AIT/DSI/FIM/CMR OH Sent Received T/C/D 6/30/98 7/2/98 5/19/98 6/8/98 6/30/98 7/2/98 4/7/98 4/8/98 5/I 9/98 6/8/98 4/7/98 4/8/98 5/I 9/98 6/8/98 6/30/98 7/2/98 5/19/98 6/8/98 5/19/98 6/8/98 5/19/98 6/8/98 5/19/98 6/8/98 5/19/98 6/8/98 5/19/98 6/8/98 5/19/98 6/8/98 5/19/98 6/8/98 5/I 9/98 6/8/98 5/19/98 6/8/98 6/!0/98 6/I 0/98 6/30/98 7/2/98 4/27/98 4/28/98 D 3/25/98 3/29/98 D 6/12/98 6/16/98 6/30/98 7/2/98 4/27/98 4/27/98 D 10/6/98 10/7/98 5/19/98 5/19/98 Monday, May 01,2000 Page 1 of 2 Daily Well Ops ~t/,/'~".'~, Was the well core .~.ve_s~_~_ o. __- Comments: Are Dr)., Ditch Samples Required? .,,,es (~.And Rect6ved~'~"eg~ Analysis ~Received? ),es no Sample Set # ~ q -g- Monday, May 01,2000 Page 2 o1'2 BP EXPLORATION BP Exploration (Alaska)Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, AIaska 99519-6612 (907) 561-5111 January 28, 2000 Commissioner Robert Christenson Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Extension of Operation Shutdowns NWE 1-0 lA, 1-02, 2-01 Prudhoe Bay Field C( N =, D£NTIAL Dear Commissioner Christenson' Please find the attached requests (Forms 10-403 Application For Sundry Approval) to extend operation shutdowns for another year (until April 2001) on wells NWE 1-01A, 1- 02, and 2-01. The requests are submitted in accordance with the requirements of 20 AAC 25.072. If you need additional information, please contact Bill Smalstig (Arco) at 263-4319 or Steve Deckert (BPXA) at 564-4128. NWE 1-01A, 1-02, and 2-01 were appraisal wells drilled from ice pads in the western portion of the Prudhoe Bay Unit during the period of January through April 1998. The wells were left in a mechanically safe condition which would allow us to resume either further testing or development completion operations. One year operation shutdowns were granted in April 1998 and extended in May 1999. Since the drilling of the wells, the NWE owners have made significant progress in evaluating the drilling results of these wells and potential development for the area. Consequently, Arco has filed for gravel permits and has plans to lay gravel out to wells NWE 1-01A and NWE 1-02 during the spring of this year. The gravel road will allow drilling and testing 12 months of the year, not just during winter ice season. The owners of these Kuparuk wells are working with the IPA, NWE Schrader Bluff, and PBU Schrader Bluff Owners to progress a consensus Western Region. development plan. These owners are currently engaged in a conceptual engineering effort to better define pad and pipeline requirements for 'the area. Extension of the operations shutdowns for NWE 1-01A, 1-02, and 2-01 is necessary to preserve additional appraisal, testing and/or development options at these locations. Joe Hurliman, Team Leader Central North Slope Asset- Western Developments BPXA JH/sld Enclosures (3) Alasl<a Oi~ & Gas Cons. COia]IISS~ Anchorage STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION cOIviMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: E~ Development ~] Exploratory ~] Stratigraphic E~ Service 4. Location of well at surface 2513' NSL, 3918' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 4379' NSL, 2212' WEL, SEC. 34, T12N, R11E, UM At effective depth At total depth 4447' NSL, 2150' WEL, SEC. 34, T12N, R11E, UM 6. Datum Elevation (DF or KB) KBE = 77.20' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number NWE 1-02 9. Permit Number 98-32 10. APl Number 50-029-22865 11. Field and Pool Prudhoe Bay Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured 7583 feet true vertical 7019 feet Effective depth: measured 7488 feet true vertical 6925 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 110' 20" 2797' 9-5/8" 7548' 7" Plugs (measured) Junk (measured) Cemented 260 sx Arctic Set (Approx.) 349 sx "G", 1029 sx CS III, 44 sx "G" 490 sx Class "G" MD TVD 110' 110' 2827' 2605' 7575' 6934' Perforation depth: measured true vertical Kuparuk C1 7168'-7188' Kuparuk C3 7079.5'-7085.5' 6532'-6552', 6543'-6451' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 6895' MD Packers and SSSV (type and measured depth) 7" Baker S-3 @ 6858' MD RECEIVED 02 2000 Oil & Gas Cons. Commiss/o~ Anchorage 13. Attachments [~ Description summary of proposal E~ Detailed operations program r-IBOP sketch 14. Estimated date for commencing operation October 01,2000 to April 01,2001 16. If proposal was verbally approved Name of ap..prover Date appr~gx.ed contact Engineer Name/Number: Bill Smalstig, 263-4319 17.Signedl hereby certify that th~ foregoin~ i~,.L[ Lr JoeHurliman ""~0~,,. '~"'~ ~'"""/~'"V ~ 15. Status of well classifications as: [~ Oil E~] Gas [~] Suspended Service Prepared By Name/Number: Bill Smalstig, 263-4319 true and correct to the best of my knowledge Title Team Leader Commission Use Only Conditions of Approval: Notify Commission so representative may witness I Approva~ No. Plug integrity__ BOP Test__ Location clearance____ ' ...... '~ Mechanical Integrity Test ___ Subsequent form required 10- ~..,~-~e_ ~¢_a\\~,.,a~,--,. T~._c.;v,a~:~ ORIGINAL SIGNED. BY ¢¢.~o~,ove~ OO~Y Approved by order of the Commission ~k~., ,~,, ~ ~,;~, ..... .~.~.... _ ~,,~,~(~,,.. Commissioner Date ,:~ Form 10-403 Rev. 06/15/88 ........ ~,,o~,, .. ~, /',~/':~ ~ %~_._~_~~ Submit In Triplicate NWE 1-02 Sundry Status: Operation Shutdown Original date Sundry approved: 6/19/98 Extension of Shutdown approved: 5/6/99 Post Drilling Status: · The well is fully cased and cemented and has 26 ft of perforations in the 7" casing. · All surface equipment is installed. The tree was pressure tested to 5000 psi. · The well has a 3-1/2" tubing string with a packer and was pressure tested to 4000 psi. · The tubing string has 2 wireline plugs set at 6883'md and 499'md. · The well is freeze protected with diesel from surface to 2000' on the Inner Annulus and surface to 2300' on the tubing. · All the gas lift mandrels in the tubing string have been dummied off. · The Inner Annulus (3-1/2" tbg x 7" csg) was pressure tested to 3500 psi. · The well has had 2 fracture stimulations in the Kuparuk C 1 and C3 sands. · Prior to setting wireline plugs the well was capable of flowing 100-200 bopd from the existing perfs. · The most prolific zone, the Kuparuk C-4 sand has not yet been perforated. Current Status: · Permit to lay gravel to N'WE pad 1 location requested. · Plans to lay gravel to 'N'W'E pad 1 in March/April 2000. Request/Way forward' Extend Shut Down of Operations status. Continue monitoring wells during Otter flights. Review/Update tentative well plans with AOGCC by April, Tentative Plans* Potential testing of existing wells at Pad 1 Plans to drill 1-2 additional wells off gravel Plans to drill 1 additional appraisal well offiCE Construct facilities/Drill additional wells at Pad 1 Date 4Q/2000 4Q/2000 1Q/2001 2001-2004 *Funding of plans has not yet been obtained by partners. CIW, 4-1/16', 5,000 psi Ac' ,,ualor,: Baker, "CAC' Wellhead: FMC, 13-5/8', 5,000 psi /M " 9.3 #/~t, L-80, 8 rd, EUF_., od Tubing. J~D = 2.992', Capacity = 0.008706 bbls~ nwn-squeezed 9-5/83(7' nulus with 51 Bbls cement l9-5/8', 47#/ft, 1 L-80, Btrs A/B Mod 55 m enting Stage Collar with Bbls cement Perforation Summary REF LOG: BHC/GR (xx/xx/xx) SIZE I SPF INTERVAL STATUS __ 2-1/2" 8 7168- 7188 Open Frac'd 2-1/2" 4 7079.5 - 7085.5 Open Frac'd ~Open I Sqz'd 7079.5 - 7085.5' Perfs Peris NWE 1-02 Bev =77.2' BFBev =50.. GLE~v =44 ' Ice Pad Elev :46.3' HE 1/2' 'X" Nipple, S, 2.813' ID Gas Uft Mandrels With Dummies Ca.mco~ KBG-2-LSr 1.5" Pocket 3I 3,220I 2I 5,4~3' I ~ I ~,~1~' I 3-1/2', 'X' Nipple 2.813" ID 7" Baker 'S-3" Packer ID 3-1/2", 'XN'; Nipple 13" ID, 2.75" NoGo WLEG 1 -I 16,896'1 7168 - 7188' Frac Proppant [7,450~J-~- ~, ~ ~,490 '~' . Cemented with 50 Bbls I ~ ' I~ O3/28/.98 I ML 4/le7/98 JSLD Shut Down Of Operations ! ~.O~o~!'~1:!!!~k1 B a) ALAS, .. OIL AND GAS CONSERVATION .__ ,v,MISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 8. 2513' NSL, 3918' WEL, SEC. 34, T12N, R11E, UM At top of productive interval 9. 4379' NSL, 2212' WEL, SEC. 34, T12N, R11E, UM At effective depth At total depth 4447' NSL, 2150' WEL, SEC. 34, T12N, R11E, UM 6. Datum Elevation (DF or KB) KBE = 77.20' 7. Unit or Property Name Prudhoe Bay Unit Well Number NWE 1-02 Permit Number 98-32 10. APl Number 50-029-22865 11. Field and Pool Prudhoe Bay Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured 7583 feet true vertical 7019 feet Effective depth: measured 7488 feet true vertical 6925 feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor Surface Intermediate Production Liner 110' 20" 2797' 9-5/8" 7548' 7" Cemented 260 sx Arctic Set (Approx.) 349 sx "G", 1029 sx CS III, 44 sx "G" 490 sx Class "G" MD TVD 110' 110' 2827' 2605' 7575' 6934' Perforation depth: measured true vertical Kuparuk Cl 7168'-7188' Kuparuk C3 7079.5'-7085.5' 6532'-6552',6543'-6451' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 6895' MD Packers and SSSV (type and measured depth) 7" Baker S-3 @ 6858' MD ORIGINAL RECEIVED 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation June 19, 2000 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Bill Smalstig, 263-4319 hereby certify that.thb-~,sregoing.is.!r,u/e and correct to the best of my knowledge 1 7. I Signed .... ., Joe Hurliman :" ~ "t -"~'-"~'" '"~"~"' "- "" ............ Title Team Leader 15. Status of well classifications as: [] Oil [] Gas F-I Suspended Service Prepared By Name/Number: Bill Smalstig, 263-4319 Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ..... BOP Test .... Location clearance Mechanical Integrity Test .... Subsequent form required 10-_~_O_~ ..... Approved by order of the Commission 'ORIGINAL SIGNED BY I,.,,,~,', - ,,~e~ Commissioner Form10-403 Rev. 06/15/88 Robert N. Christenson ~-'~ ' ' .... Date,_'~"/~ '''~/~ Submit In Triplicate ,', Tree: CIW, 4-1/16", 5,000 psi Actuator: Baker, "CAC" Wellhead: FMC, 13-5/8", 5,000 psi i~D-1/2", 9.3 #1ft, L-80, 8 rd, EUE, B Mod Tubing. = 2.992", Capacity = 0.008706 bbls/ft aDown-squeezed 9-5/8"x7" nnulus with 51 Bbls cement 9-5/8", 47#/ft, I L-80, Btrs A/B MOd iCementing Stage Cellar with 85 Bbls cement Perforation Summa~ REF LOG: BHC/GR (xx/xx/xx) SIZE SPF INTERVAL STATUS 2-1/2" 8 7168 - 7188 Open Frac'd 2-1/2" 4 7079.5 - 7085.5 Open Frac'd ~Open I Sqz'd 7079.5- 7085.5' Per/s Perfs 7168 - 7188' NWE 1-02 O ,,, K~ Elev =77.2' BF Elev --50.4' GL Elev =44.1' Ice Pad Elev = 46.3' 3-1/2" 'X" Nipple, HES, 2.813" IDI ~ Gas Lift Mandrels With Dummies Camco~ KBG-2-LSr 1.5" Pocket 'X' Nipple 2.813" ID 7" Baker "S-3" Packer 3.875" ID 3-1/2", 'XN'; Nipple 2.813" ID, 2.75" NoGo WLEG I 16,88e'1 Frac Proppant 7", 26#/~t, L-80, Btm NB MOd Cemented with 50 Bbls Date 4/17/98 IRev. By MI ISLD 7,450" Comments Initial C(3m.nletion Shut Down Of Operations North West Eileen WELL: NWE 1-02 APl No: 50-029-22865 Sec. 34 R11 E BP Exploration (Alaska) NWE 1-02 Sundry Status: Operation Shutdown Date Sundry Approved: 6/19/98 Current Status: · The well is fully cased and cemented and has 26 ft of perforations in the 7" casing. · All surface equipment is installed. The tree was pressure tested to 5000 psi. · The well has a 3-1/2" tubing string with a packer and was pressure tested to 4000 psi. · The tubing string has 2 wireline plugs set at 6883'md and 499'md. · The well is freeze protected with diesel from surface to 2000' on the Inner Annulus and surface to 2300' on the tubing. · All the gas lift mandrels in the tubing string have been dummied off. · The Inner Annulus (3-1/2" tbg x 7" csg) was pressure tested to 3500 psi. · The well has had 2 fracture stimulations in the Kuparuk C 1 and Kuparuk C3 sands. · Prior to setting wireline plugs the well was capable of flowing 100-200 bopd from the existing perfs. · The most prolific zone, the Kuparuk C-4 sand has not yet been perforated. Request/Way forward: ;DP OONTii~.~:!jii!~i',;'?~/i~L · Extend Shut Down of Operations status. · Continue monitoring wells during Otter flights. · Review/Update tentative well plans with AOGCC by April, 2000. Tentative Plans* Submit gravel permit applications at NWE Lay gravel for road and pad to NWE pad 1 location Potential testing of existing wells at Pad 1 Construct facilities/Drill additional wells at Pad 1 Date Summer, 1999 Winter, 1999/2000 Summer, 2000 2001-2004 *Funding of plans has not yet been obtained by partners. RECEIVED Naeka Ofl & Gas Cons. Comm~lon Anchorage STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION CO',,,,¢IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ~Operation Shutdown ~-~ Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2513' NSL, 3918' WEL, SEC. 34, T12N, R11E At top of productive interval 4379' NSL, 2212' WEL, SEC. 34, T12N, R11E At effective depth 4436' NSL, 2160' WEL, SEC. 34, T12N, R11E At total depth 4447' NSL, 2150' WEL, SEC. 34, T12N, R11E E~] Stimulate ~ Alter Casing E~ Plugging E~ Perforate [] Repair Well []Other Type of well: [] Development [~ Exploratory ~ Stratigraphic [--]Service 6. Datum Elevation (DF or KB) KBE = 74.1 AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number NWE 1-O2 9. Permit Number / Approval No. 98-32 10. APl Number 50-029-22865 1. Field and Pool Prudhoe Bay Field/Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured 7583 feet true vertical 7019 feet Effective depth: measured 7488 feet true vertical 6925 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 110' 20" 2797' 9-5/8" 7548' 7" Plugs (measured) Junk (measured) Slickline XXN plug @ 6868' WLM Slickline XX pluq @ 476' WLM Cemented 260 sx Arctic Set (Approx.) 349 sx "G", 1029 sx CS III, 44 sx "G" 490 sx Class "G" MD 110' 2827' 7575' TVD 110' 2605' 6934' Perforation depth: measured true vertical Kuparuk C1 7168'-7188' Kuparuk C3 7079.5'-7085.5' 6532'-6552', 6543'-6451' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 6895' MD Packers and SSSV (type and measured depth) 7" Baker S-3 @ 6858' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments L--] Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [~ Oil [--] Gas E~ Suspended Service 17. I hereby certify that the foregoir~ i~t'i~Ue and correct to the best of my knowled,_d_ge Signed~-,~, "~kcL-~"¥'---Title ~'0,~"~' L-~,',~%~,e¢,-.. Prepared By IXk~e/Number: M Sloan 564-5127 , ~,, Submit In Duplic Form 10-404 Rev. 06/15/88 PRUDHOE BAY, ALASKA TO: FROM: Well Name: Main Category: Sub Category: Operation Date: AFE Satellite Group M.D. Martin NWE 1-02 Completion Wireline 04-20-98 4P 1140 SIP = 550 lAP = 0 OAP = 450 WHT - S/I Rig up HB&R. Pressure test to 3,500 psi. Pump 30 bbls of 180° sea water down tubing to clear thick crude from tubing. Follow with 20 bbls of warm diesel. Freeze protected to 2,300'. Pump 53 bbls of warm diesel down inner annulus to freeze protect to 2,000'. RIH W/ RIH W/ RIH W/ RIH W/ RIH W/ PLUG MIRU HES #2. RIH W/3 1/2 X-LINE W/XXN PLUG W/3 1/2 EQ. DEVICE TO XN @ 6868' WLM POOH. BLEED OFF WHP TO 0 PSI. PLUG HELD. GOOD SET. KNUCKLE, 3 1/2 OM-l, 7" EXT., 1 5/8" JDS TO STA. #2 @ 5442' WLM POOH W/GLV SAME TO STA. #3 @ 3207' WLM, POOH W/GLV SAME W/DGLV TO STA. #3 @ 3207' WLM, POOH GOOD SET SAME W/DGLV TO STA. #2 @ 5442' WLM, POOH GOOD SET 3 1/2 X-LINE W/XX PLUG W/3 1/2 EQ. DEVICE. TO X-NIPPLE @ 476' WLM, POOH W/ RIH W/SAME W/X-LINE PINNED W/DOUBLE STEEL PIN IN TOP, TO SAME DEPTH, POOH W/PLUG TOP PINS MARKED SLIGHTLY RIH W/SAME W/1 STEEL PIN IN TOP OF X-LINE TO SAME DEPTH, POOH RIH W/3 1/2 CHECK SET TO SAME, POOH TOOL SHEARED GOOD SET. RDMO WELL LEFT SHUT IN NOTE: MAX PSI. W/XXN PLUG SET @ 550 psi. MAX PSI. W/XX PLUG SET @ 0 psi. BOTH PLUGS HAVE 31/2 EQUALIZING DEVICES. NO BACK PRESSURE VALVE SET. SWAB, WING AND MASTER VALVES CLOSED. TD Wireline Depth: N/A TD Corrected Depth: N/A Diesel Used [73 bbls 1 Sea Water 130 bbls [ Tree: CIW, 4-1/16", 5,000 psi Actuator: Baker, "CAC" Wellhead: FMC, 13-5/8", 5,000 psi NWE 1-02 Confidential Well KB Elev =77.2' BF Elev =50.4' GL Elev =44.1' Ice Pad Elev = 46.3' 3-1/2" 'X" Nipple, I "ES, 2.813" ID I 1/2", 9.3 #Iff, L-80, 8 rd, EUE, B Mod Tubing. = 2.992", Capacity = 0.008706 bbls/ft IDown-squeezed 9-5/8"x7" annulus with 51 Bbls cement I9-5/8", 47#/ft, I L-80, Btrs A/B Mod ICementing Stage Collar with 85 Bbls cement 14,822' ~ Gas Lift Mandrels With Dummies Camco, KBG-2-LS, 1.5" Pocket !o~.I MD(BKB) 3,220 5,453' 6,818' TVDss Dev. Perforation Summary REF LOG: BHC/GR (xx/xx/xx) SIZE SPF INTERVAL STATUS 2-1/2" 8 7168 - 7188 Open Frac'd 2-1/2" 4 7079.5 - 7085.5 Open Frac'd Open I Sqz'd Perfs Perfs 7079.5- 7085.5' 3-1/2", 'X' Nipple 813" ID Baker "S-3" Packer ~.875" ID 3-1/2", 'XN'; Nipple ID, 2.75" NoGo (E-Line Depth 16,846'1 16,858'1 16,8s4'l 6,896' 7168- 7188' Frac Proppant I PBTDI I 7", 26#/ft, L-80, Btrs A/B Mod I Cemented with 50 Bbls ] 7,450'-~-~,~ Date 03/28/98 4/17/98 Rev. By ML SLD Comments Initial Completion Shut Down Of Operations North West Eileen WELL: NWE 1-02 APl No: 50-029-22865 Sec. 34, T12N, R11E BP Exploration (Alaska) STATE OF ALASKA ALASKA",_.,L AND GAS CONSERVATION COi, ~IISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [~ Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: E~ Development i~ Exploratory E~ Stratigraphic [--]Service 4. Location of well at surface 2513' NSL, 3918' WEL, SEC. 34, T12N, R11E At top of productive interval 4379' NSL, 2212' WEL, SEC. 34, T12N, R11E At effective depth 4436' NSL, 2160' WEL, SEC. 34, T12N, R11E At total depth 4447' NSL, 2150' WEL, SEC. 34, T12N, R11E Datum Elevation (DF or KB) KBE = 74.1 AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number NWE 1-02 9. Permit Number 98-32 10. APl Number 50-029-22865 11. Field and Pool Prudhoe Bay Field/Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured 7583 feet true vertical 7019 feet Effective depth: measured 7488 feet true vertical 6925 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 110' 20" 2797' 9-5/8" 7548' 7" Plugs (measured) Junk (measured) Slickline XXN plug @ 6868' WLM Slickline XX plum @ 476' WLM Cemented 260 sx Arctic Set (Approx.) 349 sx "G", 1029 sx CS III, 44 sx "G" 490 sx Class "G" MD 110' 2827' 7575' TVD 110' 2605' 6934' Perforation depth: measured true vertical Kuparuk C1 7168'-7188' Kuparuk C3 7079.5'-7085.5' 6532'-6552', 6543'-6451' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 6895' MD Packers and SSSV (type and measured depth) 7" Baker S-3 @ 6858' MD ORIGINAL 13. Attachments r-I Description summary of proposal I--I Detailed operations program I--] BOP sketch 14. Estimated date for commencing operation 4/2O/98 16. If proposal was verbally approved Blair Wondzell Name of approver Contact Engineer Name/Number: 4/17/98 Date approved 15. Status of well classifications as: L~ oil F--] Gas [--[ Suspended Service Prepared By Name/Number: M Sloan 564-5127 17. I hereby certify tha~ the.foregoing/is true .and correct to the best of my knowledge Signed ""~/;' '" ~ f , ....._/~ '"'/---~Z~.'.'"/'~- ~"~'" Title Date Commission Use Only ;on~ Form itio~.of Approval: Notify Commission so representative may witness I Approval No~'~:) ""/~¥" ©°'~''' ' Plug integrity ___ BOP Test ___ Location clearance i~ ..~'" Mechanical Integrity Test Subsequent form required 10-_~¥ by order of the Commission 0avid W. Johnston Commissioner Date 0-403 Rev. 06/15/88 SUb~t In friPlicate PRUDHOE BaY, ALASKA TO: FROM: Well Name: Main Category: Sub Category: Operation Date: AFE Satellite Group M.D. Martin NWE 1-02 Completion Wireline 04-20-98 4Pl140 SIP = 550 lAP = 0 OAP: 450 WHT = S/I Rig up HB&R. Pressure test to 3,500 psi. Pump 30 bbls of 180© sea water down tubing to clear thick crude from tubing. Follow with 20 bbls of warm diesel. Freeze protected to 2,300'. Pump 53 bbls of warm diesel down inner annulus to freeze protect to 2,000'. RIH W/ RIH W/ RIH W/ RIH W/ RIH W/ PLUG MIRU HES #2. RIH W/3 1/2 X-LINE W/XXN PLUG W/3 1/2 EQ. DEVICE TO XN @ 6868' WLM POOH. BLEED OFF WHP TO 0 PSI. PLUG HELD. GOOD SET. KNUCKLE, 3 1/2 OM-l, 7" EXT., 1 5/8" JDS TO STA. #2 @ 5442' WLM POOH W/GLV SAME TO STA. #3 @ 3207' WLM, POOH W/GLV SAME W/DGLV TO STA. #3 @ 3207' WLM, POOH GOOD SET SAME W/DGLV TO STA. #2 @ 5442' WLM, POOH GOOD SET 3 1/2 X-LINE W/XX PLUG W/3 1/2 EQ. DEVICE. TO X-NIPPLE @ 476' WLM, POOH W/ RIH W/SAME W/X-LINE PINNED W/DOUBLE STEEL PIN IN TOP, TO SAME DEPTH, POOH W/PLUG TOP PINS MARKED SLIGHTLY RIH W/SAME W/1 STEEL PIN IN TOP OF X-LINE TO SAME DEPTH, POOH RIH W/3 1/2 CHECK SET TO SAME, POOH TOOL SHEARED GOOD SET. RDMO WELL LEFT SHUT IN NOTE: MAX PSI. W/XXN PLUG SET @ 550 psi. MAX PSI. W/XX PLUG SET @ 0 psi. BOTH PLUGS HAVE 31/2 EQUALIZING DEVICES. NO BACK PRESSURE VALVE SET. SWAB, WING AND MASTER VALVES CLOSED. TD Wireline Depth: N/A TD Corrected Depth: N/A Diesel Used 173 bbls I Sea Water 130 bbls I m II 03 ~ _- -0 ITl m ITl FI'I II II < BP EXPLORATION, Alaska Date: 10-06-98 Trans# 89629 NW EILEEN LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564~4166 Sw Name Log Type Rec Type Rec Date Comments ;~j~- NWE1-02 MUDLOG REP 27-Mar-98 FINAL ADT WELL SUMMARY(LIMITED) - )'57_. BOUND REPORT, DATES 3-10 TO 3-27-98 Please sign and return one copy of this transmittal letter. Thank-you, Carla Harris Petrotechnical Data Center ARCO - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips- Paul Robertson DNR - Tim Ryherd AOGCC - Howard Oakland BP - Brett Chambers OCT 07 1998 Alaska 0i! &. Gas (~D.S. C,~mmissi~. An~orage Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 06-30-98 Trans# 89220 NW EILEEN LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 ~Sw Name Log Type Rec Type Rec Date Comments NWE1-02 DSI OH 21-Mar-98 DIPOLE SONIC - RECOMPUTED~ . .~['c~-e¥~) ,,_~_,.._~r¢~ ~IWE1-02 FMS OH 21-Mar-98 FMI INTERPRETATION - HAND PICKED DIPS (60 ~.~/" t~ .- = ~ 00') N~/VE1-02 CMR OH 21-Mar-98 CMR TOTAL POROSITY WE1-02 CMR OH : 21-Mar-98 CMR TOTAL POROSITY/FMI WE1-02 DSI REP 21-Mar-98 SONIC EVALUATION WITH DIPOLE SONIC TOOL - BOUND REPORT ,NWE2-01 DSI REP 02-Apr-98 SONIC EVALUATION WITH DIPOLE SONIC TOOL - BOUND '1~' REPORT ~WE2-01 FMS OH 03-Apr-98 FMI IMAGES MSD & HAND PICKED DIPS (FMI PASS/GR/CRC) 1~1,..WE2;01FMS OH 03-Apr-98 FMI IMAGES - MSD (FMI PASS / GR/CRC) NWE2-01 FMS OH 03-Apr-98 FMI AND OPENHOLE LOGS- COMPOSITE DISPLAY (FMI/ ,.d.. PEX/AIT) NWE2-01 DSI OH 30-Mar-98 DSI- SONIC REPROCESS ~'~c~°~ ,-~/"~e..~.~¢~ lqWE2-01 DIPMETE OH 21-Apr-98 DIPMETER EVALUATION SHEET R ~IWE1-02 DIPMETE OH 08-Apr-98 DIPMETER EVALUATION SHEET R Please sign and return one copy of this transmittal letter. Thank-you, Nadene Reichert Petrotechnical Data Center ARCO - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips- Paul Robertson DNR - Tim Ryherd AOGCC - Howard Oakland BP - Brett Chambers JdL Petrotechnical Data Center, MB3-3 900 East Benson BoUlevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG CONFIDENTIAL 1. Status of Well Classification of Service Well [] Oil ~ Gas [] Suspended [---] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-32 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22865 4. Location of well at surface .....r- ' . l~~.~,,,~f 9. Unit or Lease Name 2513'NSL, S918'WEL, SEC. S4, T12N, R11E, UM ~///.,[/~ ,' ~¢., ~., ,~i Prudhoe Bay Unit ....................... i,: '~,.~¢~:~ ~ At top of productive interval i"0. Well Number 4379' NSL, 2212' WEb, SEC. 34, T12N, R11E, UM '" .'....i ' At total depth ~.. i :'"'"~'~'~-~-.'~-' t~ NWE 1-02 ....... i.:..'.',~~f. 11. Field and Pool 4447' NSL, 2150' WEb, SEC. 34, T12N, R11 E, UM" - ............. Prudhoe Bay Field / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Oil Pool KBE -- 77.20'I ADb 028239 12. Date Spudded 113. Date I.D. Reached I 14. Date Comp., Susp., or ^band.115."Water depth, if offsh0re 116. No. of Cornpletions 3/9/98 . 3/21/98 4/2/98 ~ .... N/A MS.L[ One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth v~'~'~re SSSV set 121. Thickness'of Permafrost 7583 7019 FT 7488 6925 FT [~]Yes [~]No] N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, ESS, GR, RES, RES / AlT, DT / BHC, CNL, LDL, Caliper, SP, UREa, Dipole Sonic, CDL, CUR, FMI, RFT, EMS, USIT, GYRO .2.'3'..: CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT P,~JLLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 30'; "2827i' 12-1/4" 3'49 sx "~', 1029 sx CS III, 44 sx 'G' 7" 26# L-80 27' 7575' 8-1/2" 490 sx Class 'G' ......... .... "24~ Perforat'ions open to Production (MD+TVD of Top and 25. TUBING RECORD .... ',"C."";'"~ ..... ' · Bottom and interval, size and number) . . SizE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 2-1/2" Gun Diameter, 8 spf §~1/2", 9.3,#, L-80 6895' 6858' MD TVD MD TVD 7080'-7086' 6522'-6528' 7168'-7188' 6609'-6629' ~ ............. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED "Freeze Protect with 70 Bbls of ~'iesel '"Frac'd, 7168'-7188' 15588# 16/20 Carbolite Frac'd, 7080'-7086' 5775# 16/20 Carbolite , ., .......................... ..................... i\i A ..27' . ............ PRODUCTI°N -F~'F ....... t"t ~L.¢t'l ~-', i ¢-'' .' ..... Date First Production* ....... I Mei'~'°d of Operation (Flow'ing, gas lift, et(~ii .............. ~ ~ '~ i '~,.~ ~ ~ ~ ~' Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE IGAS-(~'IL"RATI© 4/17/98 51.5 TEST PERIOD 253 TOO small 22 128I 429 FioTM Tubing Casing Pressure CALCULATED OIL~BBL GAs-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 70 0 24-HOUR RATE 135 58 0 24.7 .28. CORE DATA Brief descriPti°n ~f lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Kuparuk C: Very fine upper to silty sandstone, well to moderately sorted, good to tight porosity, fluorescence and cut, glauconite and siderite with trace pyrite, mica, and carbonaceous material. E-line interpretation of sandstone is "pay". Kuparuk C: Black silty to sandy shale with trace glauconite and mica flakes, no visable fluorescence or cut. Please See Attached: BP Exploration Core Chip Sample Descriptions. - Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Subsea %5 2104 1952 See Attached T-3 2653 2451 K-15 2981 2741 Ugnu 2990 2749 K-13/Wsak 4740 4300 K-12 5037 4561 K-10 5442 4918 K-5 6197 5596 K-2 6700 6073 Top HRZ 6767 6138 Base HRZ 6874 6243 K-1 695O 6317 Kuparuk D Missing Missing Kuparuk C 7020 6386 Kuparuk B/LCU 7179 6543 LCU 7179 6543 Kuparuk A 7315 6677 Miluveach (Base Kuparuk) 7425 6786 31. List of Attachments Summary of Daily Drilling Reports, Surveys 321 I hereb~ certify that the foregoing is true and correct to the best of my knowledge Signed ~LT._~ .._. ~¢,.~, ..... ~ 6 [I r,) ~ % Dan Stone .................. Title Engineering Supervisor ...... Date ............... NWE 1-02 98-32 Prepared By Name/Number: Terrie Hubble, 564-4628 : Well Numbe, r, ................. Perm,.!~ No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 07 Mar 98 08 Mar 98 09 Mar 98 10 Mar 98 11 Mar 98 EX NWE#1 Progress Report Well NWE 1-02 Rig Nabors 18E Page Date Duration Activity 21:30-00:00 00:00-00:30 00:30-06:00 06:00-06:30 06:30-12:00 12:00-12:30 12:30-13:30 13:30-17:30 17:30-19:00 19:00-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-03:00 03:00-04:30 04:30-06:00 06:00-12:00 12:00-12:30 12:30-18:00 18:00-19:00 19:00-00:00 00:00-00:30 00:30-01:30 01:30-02:00 02:00-02:30 02:30-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-11:00 11:00-12:00 12:00-12:30 12:30-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-03:00 03:00-05:00 05:00-05:30 05:30-06:00 06:00-07:30 07:30-09:00 09:00-09:30 09:30-10:00 10:00-12:00 12:00-12:30 12:30-16:00 16:00-17:30 17:30-17:45 17:45-18:15 18:15-19:00 19:00-19:15 2-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1 hr 4 hr 1-1/2 hr 3-1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 6 hr 1/2 hr 5-1/2 hr 1 hr 5 hr 1/2 hr 1. hr 1/2 hr 1/2 hr 3-1/2 hr 2 hr 1 hr 1 hr 1 hr 1 hr 1/2 hr 10-1/2 hr 1 hr 1/2 hr 1/2 hr 1 hr 1 hr 2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/4 hr 1/2 hr 3/4 hr 1/4 hr Rigged down Drillfloor / Derrick Held safety meeting Rig moved 60.00 % Rig moved 100.00 % (cont...) Rigged up Drillfloor / Derrick Held safety meeting Rigged up SCR Rigged up Divertor Rigged up Liner Installed Drillfloor / Derrick Held safety meeting Rigged up Drillstring handling equipment Held safety meeting Tested Divertor Tested High pressure lines Made up BHA no. 1 Drilled to 260.0 ft Drilled to 666.0 ft (cont...) Held safety meeting Drilled to 1096.0 ft Cleared Mud pumps Drilled to 1405.0 ft Held safety meeting Drilled to 1498.0 ft Pulled out of hole to 683.0 ft R.I.H. to 1498.0 ft Drilled to 1832.0 ft Drilled to 1933.0 ft (cont...) Circulated at 1933.0 ft Drilled to 1991.0 ft Circulated at 1991.0 ft Drilled to 2024.0 ft Held safety meeting Drilled to 2842.0 ft Circulated at 2842.0 ft Held safety meeting Circulated at 2842.0 ft Pulled out of hole to 683.0 ft R.I.H. to 2842.0 ft Circulated at 2842.0 ft Dropped EMSS survey barrel Pulled out of hole to 2500.0 ft Pulled out of hole to 683.0 ft (cont...) Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 650.0 ft (9-5/8in OD) Held safety meeting Ran Casing to 2827.0 ft (9-5/8in OD) Circulated at 2827.0 ft Held safety meeting Mixed and pumped slurry - 72.000 bbl Displaced slurry - 200.000 bbl Functioned DV collar 1 06 May 98 Facility Date/Time 12 Mar 98 13 Mar 98 14 Mar 98 15 Mar 98 EX NWE# 1 Progress Report Well NWE 1-02 Rig Nabors 18E Duration Activity 19:15-20:00 20:00-21:00 21:00-21:30 21:30-23:30 23:30-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-14:30 14:30-15:30 15:30-16:30 16:30-17:30 17:30-19:30 19:30-20:30 20:30-21:00 21:00-23:00 23:00-23:30 23:30-00:00 00:00-00:30 00:30-02:00 02:00-03:00 03:00-06:00 06:00-12:00 12:00-12:30 12:30-15:30 15:30-16:00 16:00-16:45 16:45-18:00 18:00-00:00 00:00-00:30 00:30-06:00 06:00-11:00 11:00-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-00:00 00:00-00:30 00:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:30 09:30-12:00 12:00-12:30 12:30-14:30 14:30-15:00 3/4 hr 1 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 1-1/2 hr 4 hr 1/2 hr 4 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 1 hr 1 hr 2 hr 1 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1 hr 3 hr 6 hr 1/2 hr 3 hr 1/2 hr 3/4 hr 1-1/4 hr 6 hr 1/2 hr 5-1/2 hr 5 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 11 hr 1/2 hr 5-1/2 hr 1/2 hr 1 hr 1 hr 1 hr 2-1/2 hr 1/2 hr 2 hr 1/2 hr Circulated at 2041.0 ft Mixed and pumped slurry - 361.000 bbl Displaced slurry - 145.000 bbl Rigged down Cement head Rigged down Divertor Held safety meeting Rigged down Divertor Rigged up BOP stack Rigged up BOP stack (cont...) Tested BOP stack Installed Wear bushing Made up BHA no. 2 Held safety meeting Made up BHA no. 2 R.I.H. to 1877.0 ft Serviced Block line R.I.H. to 2038.0 ft Drilled installed equipment - DV collar R.I.H. to 2730.0 ft Circulated at 2730.0 ft Tested Casing Held drill (Kick (well kill)) Drilled cement to 2842.0 ft Drilled to 2862.0 'ft Circulated at 2862.0 ft Held safety meeting Performed formation integrity test Circulated at 2862.0 ft Drilled to 3250.0 ft Drilled to 3990.0 ft (cont...) Held safety meeting Drilled to 4458.0 ft Circulated at 4458.0 ft Pulled out of hole to 2827.0 ft R.I.H. to 4458.0 ft Drilled to 4984.0 ft Held safety meeting Drilled to 5550.0 ft Drilled to 5979.0 ft (cont...) Circulated at 5979.0 ft Pulled out of hole to 4500.0 ft Held safety meeting R.I.H. to 5979.0 ft Drilled to 6759.0 ft Held safety meeting Drilled to 7042.0 ft Drilled to 7062.0 ft (cont...) Circulated at 7062.0 ft Pulled out of hole to 4853.0 ft R.I.H. to 7062.0 ft Circulated at 7062.0 ft Held safety meeting Circulated at 7062.0 ft Held safety meeting Page Date 2 06 May 98 Facility Date/Time 16 Mar 98 17 Mar 98 18 Mar 98 EX NWE#1 Progress Report Well NWE 1-02 Rig Nabors 18E Page Date 15:00-18:00 Duration Activity 3 hr Circulated at 7062.0 ft 18:00-18:30 18:30-19:00 19:00-20:30 20:30-21:30 21:30-22:00 22:00-00:00 00:00-00:30 00:30-03:00 03:00-06:00 06:00-07:00 07:00-08:30 08:30-09:00 09:00-11:00 11:00-12:00 12:00-12:30 12:30-15:30 15:30-15:45 15:45-1.6:30 16:30-18:00 18:00-19:30 19:30-20:30 20:30-21:30 21:30-22:00 22:00-22:45 22:45-23:15 23:15-00:00 00:00-00:30 00:30-01:00 01:00-04:30 04:30-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-09:30 09:30-10:00 10:00-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-15:30 15:30-17:00 17:00-18:00 18:00-19:00 19:00-20:30 20:30-21:00 21:00-21:30 21:30-22:00 22:00-22:30 22:30-23:00 23:00-23:30 23:30-00:00 00:00-00:30 1/2 hr Pulled out of hole to 5973.0 ft 1/2 hr R.I.H. to 7062.0 ft 1-1/2 hr Circulated at 7062.0 ft 1 hr Pulled out of hole to 6159.0 ft 1/2 hr R.I.H. to 7062.0 ft 2 hr Circulated at 7062.0 ft 1/2 hr Held safety meeting 2-1/2 hr Circulated at 7062.0 ft 3 hr Pulled out of hole to 2827.0 ft 1 hr Pulled out of hole to 669.0 ft (cont...) 1-1/2 hr Pulled BHA 1/2 hr Held safety meeting 2 hr Made up BHA no. 3 1 hr R.I.H. to 2600.0 ft 1/2 hr Held safety meeting 3 hr R.I.H. to 2946.0 ft 1/4 hr Pulled out of hole to 2827.0 ft 3/4 hr Circulated at 2827.0 ft 1-1/2 hr Pulled out of hole to 658.0 ft 1-1/2 hr Pulled BHA 1 hr Made up BHA no. 4 1 hr R.I.H. to 2919.0 ft 1/2 hr Reamed to 3000.0 ft 3/4 hr Circulated at 3000.0 ft 1/2 hr Reamed to 3076.0 ft 3/4 hr Circulated at 3076.0 ft 1/2 hr Held safety meeting 1/2 hr Circulated at 3076.0 ft 3-1/2 hr R.I.H. to 4310.0 ft 1-1/2 hr Pulled out of hole to 1500.0 ft 1 hr Pulled out of hole to 456.0 ft 1/2 hr Pulled BHA 1/2 hr Made up BHA no. 4 1-1/2 hr R.I.H. to 2827.0 ft 1/2 hr Circulated at 2827.0 ft 1 hr R.I.H. to 4289.0 ft 1 hr Washed to 4289.0 ft 1/2 hr Held safety meeting 1/2 hr R.I.H. to 6956.0 ft 1/2 hr Washed to 7062.0 ft 2 hr Circulated at 7062.0 ft 1-1/2 hr Pulled out of hole to 456.0 ft 1 hr Pulled BHA 1 hr Made up BHA no. 5 1-1/2 hr R.I.H. to 2827.0 ft 1/2 hr Circulated at 2827.0 ft 1/2 hr R.I.H. to 3262.0 ft 1/2 hr Washed to 3262.0 ft 1/2 hr R.I.H. to 4022.0 ft 1/2 hr Washed to 4022.0 ft 1/2 hr R.I.H. to 4125.0 ft 1/2 hr Washed to 4125.0 ft 1/2 hr Held safety meeting 3 06 May 98 Facility Date/Time 19 Mar 98 20 Mar 98 21 Mar 98 22 Mar 98 23 Mar 98 EX NWE# 1 Progress Report Well NWE 1-02 Rig Nabors 18E Page Date Duration Activity 00:30-01:00 01:00-01:30 01:30-02:30 02:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-12:00 12:00-13:30 13:30-15:00 15:00-21:00 21:00-00:00 00:00-00:30 00:30-03:00 03:00-06:00 06:00-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-15:30 15:30-00:00 00:00-00:30 00:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-14:00 14:00-00:00 00:00-00:30 00:30-06:00 06:00-10:00 10:00-12:00 12:00-12:30 12:30-13:00 13:00-15:00 15:00-19:30 19:30-21:30 21:30-23:00 23:00-00:00 00:00-00:30 00:30-03:30 03:30-06:00 06:00-12:00 12:00-12:30 12:30-14:45 14:45-16:00 16:00-18:30 18:30-22:00 22:00-02:00 02:00-06:00 06:00-10:00 1/2 hr 1/2 hr 1 hr 3-1/2 hr 1 hr 1 hr 1 hr 3 hr 1-1/2 hr 1-1/2 hr 6 hr 3 hr 1/2 hr 2-1/2 hr 3 hr 6 hr 1/2 hr 1 hr 1/2 hr 1-1/2 hr 8-1/2 hr 1/2 hr 2-1/2 hr 1 hr 1 hr 1 hr 5 hr 1 hr 1/2 hr 1-1/2 hr 10hr 1/2 hr 5-1/2 hr 4 hr 2 hr 1/2 hr 1/2 hr 2 hr 4-1/2 hr 2 hr 1-1/2 hr I hr 1/2 hr 3 hr 2-1/2 hr 6 hr 1/2 hr 2-1/4 hr 1-1/4 hr 2-1/2 hr 3-1/2 hr 4 hr 4 hr 4 hr R.I.H. to 4469.0 ft Circulated at 4469.0 ft R.I.H. to 7062.0 ft Circulated at 7062.0 ft Circulated at 7062.0 ft Pulled out of hole to 6085.0 ft R.I.H. to 7062.0 ft Cored to 7115.0 ft Flow check R.I.H. to 7115.0 ft Pulled out of hole to -0.0 ft Laid out Aluminium sleeve core Held safety meeting Made up BHA no. 6 Circulated at 7115.0 ft Cored to 7132.0 ft Held safety meeting Cored to 7135.0 ft Flow check Circulated at 7135.0 ft Pulled out of hole to -0.0 ft Held safety meeting Made up BHA no. 7 R.I.H. to 2922.0 ft Circulated at 2922.0 ft Tested BOP stack Tested BOP stack R.I.H. to 7135.0 ft Held safety meeting Took MWD survey at 7135.0 ft Drilled to 7506.0 ft Held safety meeting Drilled to 7545.0 ft Drilled to 7583.0 ft Circulated at 7583.0 ft Held safety meeting Pulled out of hole to 6980.0 ft Took EMS survey at 7583.0 ft Pulled out of hole to -0.0 ft Pulled BHA Rigged up Lubricator Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Serviced Formation logs Conducted electric cable operations Made up BHA no. 8 4 06 May 98 Facility EX NWE# 1 Progress Report Well NWE 1-02 Page 5 Rig Nabors 18E Date 06 May 98 Date/Time 24 Mar 98 25 Mar 98 26 Mar 98 27 Mar 98 10:00-10:30 10:30-13:00 13:00-16:30 16:30-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-06:00 06:00-12:15 12:15-13:30 13:30-18:00 18:00-19:00 19:00-19:30 19:30-21:30 21:30-22:30 22:30-00:30 00:30-04:30 04:30-05:30 05:30-06:00 06:00-10:30 10:30-13:00 13:00-13:30 13:30-17:00 17:00-19:30 19:30-00:00 00:00-00:30 00:30-02:00 02:00-04:30 04:30-06:00 06:00-07:00 07:00-08:00 08:00-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-14:30 14:30-15:30 15:30-16:30 16:30-18:30 18:30-19:30 19:30-22:30 22:30-00:00 00:00-00:30 00:30-02:00 02:00-02:30 02:30-03:30 03:30-06:00 06:00-07:30 07:30-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-17:00 17:00-00:00 Duration 1/2 hr 2-1/2 hr 3-1/2 hr 7-1/2 hr I/2 hr 1/2 hr 1 hr 4 hr 6-1/4 hr 1-1/4 hr 4-1/2 hr 1 hr 1/2 hr 2 hr 1 hr 2 hr 4 hr 1 hr 1/2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 3-1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1 hr 1 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1 hr 1 hr 2 hr 1 hr 3 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 2-1/2 hr 1-1/2 hr 3-1/2 hr 1 hr 1/2 hr 1/2 hr 4 hr 7 hr Activity Circulated at 3080.0 ft R.I.H. to 7583.0 ft Circulated at 7583.0 ft Pulled out of hole to 658.0 ft Held safety meeting Pulled BHA Installed Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Rigged down Lubricator Rigged down Kelly Rigged up Pipe ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 2770.0 ft (7in OD) Circulated at 2770.0 ft Flow check Ran Casing to 6280.0 ft (7in OD) Circulated at 6280.0 ft Ran Casing to 7575.0 ft (7in OD) Circulated at 7575.0 ft Mixed and pumped slurry - 50.000 bbl Held 240.0 psi pressure on 0.000 bbl squeezed cement Held safety meeting Circulated at 4822.0 ft Mixed and pumped slurry - 85.000 bbl Rigged down Cement head Rigged up Drillfloor / Derrick Mixed and pumped slurry - 51.000 bbl Rigged up Pipe ram Rigged up Kelly Held safety meeting Rigged up Kelly Made up BHA no. 9 R.I.H. to 1500.0 ft Serviced Block line R.I.H. to 4822.0 ft Drilled installed equipment - DV collar R.I.H. to 7369.0 ft Drilled cement to 7395.0 ft Held safety meeting Drilled cement to 7395.0 ft Circulated at 7488.0 ft Tested Casing - Via string Circulated at 7488.0 ft Circulated at 7488.0 ft Pulled out of hole to 583.0 ft Pulled BHA Held safety meeting Conducted electric cable operations Conducted electric cable operations Ran Tubing to 4433.0 ft (3-1/2in OD) Facility Date/Time 28 Mar 98 29 Mar 98 EX NWE# 1 Progress Report Well NWE 1-02 Rig Nabors 18E Page Date Duration Activity 00:00-00:30 00:30-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:00 09:00-10:30 10:30-12:00 12:00-12:30 12:30-14:00 14:00-16:00 16:00-00:00 00:00-00:30 00:30-05:00 1/2 hr 1-1/2 hr I hr 1 hr 2 hr 1/2 hr 1 hr 1 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2 hr 8 hr 1/2 hr 4-1/2 hr Held safety meeting Ran Tubing to 6895.0 ft (3-1/2in OD) Installed Hanger assembly Circulated at 6895.0 ft Rigged down BOP stack Rigged down BOP stack Installed Xmas tree Tested Tubing hanger Retrieved BOP test plug assembly Tested Wellhead primary components Circulated at 2000.0 ft Held safety meeting Circulated at 2000.0 ft Serviced High pressure lines Rig moved 50.00 % Held safety meeting Rig moved 90.00 % 6 06 May 98 NWE 1-02 Well Testing & Shut-Down of Operations Summary 3/30/98: 3/31/98: 4/1/98: 4/2/98: 4/3/98: 4/4/98: 4/5/98: 4/6/98: 4/7/98: 4/8/98: 4/9/98: 4/10/98: 4/11/98: 4/12/98: 4/13/98: 4/14/98: 4/15/98: 4/16/98: 4/17/98: 4/18/98: 4/19/98: 4/20/98: 4/21/98: 4/22/98: Move in and rig up well test equipment. Continue rigging-up well test equipment. Continue rigging-up well test equipment. Pull BPV, ball & rod, and shem' valve. Tag bottom @ 7467' Continue rigging-up well test equipment. Ran GR/CCL/Gyro log. Perf'd Kuparuk C 1 from 7168-7188' with 2-1/2" HSC, 4 JSPF, Deep Penetrators. Continue rigging-up well test equipment. Re-perf Kuparuk C 1 from 7168-7188' with 2-1/2" HSC, 4 JSPF, Big Holes. Continue rigging-up well test equipment. Frac Kuparuk C-1 Sand with 15,588# proppant. Continue rigging-up well test equipment. Continue rigging-up well test equipment. Continue rigging-up well test equipment. Kuparuk C3 from 7085.5-7079.5' with 2- Continue rigging-up well test equipment. proppant. Continue rigging-up well test equipment. Continue rigging-up well test equipment. Continue rigging-up well test equipment. Continue rigging-up well test equipment. Continue rigging-up well test equipment. Wireline tag sand top @ 7321' Sand-back with coiled tubing to 7100'. Found sand-back @ 7087'. Perf'd 1/2" HSC, 4 JSPF, Big Holes Frac Kuparuk C-3 Sand with 5,775# Run generic gas lift valve design. Continue rigging-up well test equipment. Drilling rig moved off ice pad. Cleaned out proppant to 7450' with coiled tubing. Rig up well for production. Wait for coiled tubing to move off NWE 1-01A. Produce well with coiled tubing Nitrogen lift assistance. Produce well with coiled tubing, no Nitrogen. Flow well unassisted. Take surface oil and gas samples. Start rigging down well test equipment. Freeze protected tubing to 2300' with diesel. Freeze protected inner annulus to 2000' with diesel. Dummied-off gas lift mandrels. XXN plug set in tubing @ 6868' WLM. XX plug set in tubing @ 476' WLM. Rig down test equipment and clean ice pad. Rig down test equipment and clean ice pad. NWE 1-02 GEOLOGICAL MARKER SUMMARY MARKER Measured True Vertical Depth Depth Subsea (feet) (feet) Permafrost 1833 1701 T-5 2104 1952 T-3 2653 2451 K-15 2981 2741 Ugnu 2990 2749 K- 13/Wsak 4740 4300 K- 12 5037 4561 K- 10 5442 4918 K-5 6197 5596 K-2 6700 6073 Top HRZ 6767 6138 Base HRZ 6874 6243 K- 1 6950 6317 Kuparuk D Missing Missing Kuparuk C 7020 6386 Kuparuk B/LCU 7179 6543 LCU 7179 6543 Kuparuk A 7315 6677 Miluveach (Base Kuparuk) 7425 6786 TDD 7583 6942 NWE 1-02 RFT SUMMARY RFT TEST - FILE # Measured True Vertical Formation Pressure Depth Depth Subsea Pressure Gradient (~et) (~et) (PSIG) (psi/~) 2-157 3027 2782 1.275 0.458 3-158 30411 2794 1279 0.458 2-57 3340 3059 1387 0.454 5-66 4341 3948 1778 0.450 6-67 4488 4078 1833 0.449 7-68 4755 4313 1909 0.442 4-144 7023 6389 3440 0.538 5-145 7026 6393 3441. 0.538 7-147 7031 6397 3443 0.538 8-148 7032 6399 3444 0.538 9-149 7034 6400 3445 0.538 10-72 7038 6404 3443 0.538 10-150 7038 6404 3446 0.538 11-151 7043 6409 3448 0.538 12-152 7045 6411 3449 0.538 11,-73 7045 6411 3445 0.537 13-153 7051 6417 3453 0.538 14-154 7061 6427 3455 0.538 15-155 7063 6429 3456 0.538 13-75 7063 6429 3452 0.537 14-76 7083 6449 3474 0.539 16-78 7170 6534 3488 0.534 17-79 7368 6730 3430 0.510 * Crude Oil Gravity @ 7022.6' md = 24.3 degrees AP1 Test Type Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Limited draw-down Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest Normal Pretest NWE 1-02 CORE SUMMARY Start Depth End Depth Cut Recovered (feet md) (feet md) (feet) (feet) Core 4/1 7062 7115 53 49 Core/42 7115 7135 20 20 * See Attached BP Exploration Core Chip Sample Descriptions Kuparuk C: Very fine upper to silty sandstone, well to moderately sorted, good to tight porosity fluorescence and cut, glauconite and siderite with trace pyrite, mica, and carbonaceous material. E-line interpretation of sandstone is "pay". Kuparuk C: Black silty to sandy shale with trace glauconite and mica flakes, no visable fluorescence or cut. NWE 1-02 SIDEWALL CORE SUMMARY No Attempted SWC's BP Exploration,.Inc. NWE 1-02 NW EILEEN PRUDHOE BAY, ALASKA Core Chip Sample Descriptions Chips taken in 3' intervals at inner barrel cuts. Core # 1 · 7062' to 7115' Kuparuk C sands 7062' Sandstone: 7065' Sandstone: 7068' Sandstone: 7071' Sandstone: 7074' Sandstone: Dark brown to black, fine lower, trace fine upper to very fine upper, subrounded, moderately to well sorted, trace glauconite, scattered siderite cement, fine to good porosity, bright yellow fluorescence, massive milky yellow cut, light to medium amber ring cut. Medium brown, black in part, very fine lower to very fine upper, subrounded, subangular in part, well sorted, glauconitic, poor to fair porosity, patchy siderite, scattered trace disseminated pyrite, bright yellow to yellow gold fluorescence, massive milky yellow cut, medium brown ring cut. Brown to black, very fine lower, trace very fine upper, well sorted, slight trace glauconite, abundant patchy siderite cement, poor porosity, bright yellow gold fluorescence, trace patchy dull gold fluorescence, massive milky. yellow cut, light amber ring cut. Brown, black in part, very fine lower, trace very fine upper to fine lower, moderate to well sorted, slight trace glauconite, trace mica flakes, trace black carbonaceous fragments, trace patchy siderite cement, poor to good porosity, patchy bright yellow gold to bright gold fluorescence, good milky yellow cut, light amber ring cut. Medium to light brown, very fine lower, very fine upper in part, subrounded, well sorted, slight trace glauconite, trace mica, trace patchy siderite, trace patchy pyrite, fair porosity, dull yellow gold fluorescence, good streaming cut, slow diffused cut, light amber ring cut. BP Exploration, Inc. NWE 1-02 NW EILEEN PRUDHOE BAY, ALASKA Core Chip Sample Descriptions 7077' 7080' 7083' 7086' 7089' 7092' Sandstone: Sandstone: Sandstone: Sandstone: Sandstone: Sandstone: Light to medium brown, very fine upper to fine lower, well sorted slightly glauconitic, trace mica, trace patchy disseminated pyrite, trace patchy siderite, trace small siderite stringers, poor to fair porosity, patchy yellow gold fluorescence, fair to good diffused milky yellow cut, trace good streaming cut, light to medium amber ring cut. Black to dark brown, very fine upper, trace very fine lower to fine lower, subrounded, moderate to well sorted, trace glauconite, abundant siderite, bright gold fluorescence, massive yellow cut. Medium to dark brown, very fine upper to very fine lower, moderate to well sorted, trace glauconite, scattered patchy siderite, dull yellow gold fluorescence, good massive milky yellow cut, medium brown ring cut. .. Light to dark brown, black in part, very fine upper to very fine lower, moderate to well sorted, slight trace glauconite, trace disseminated pyrite, scattered siderite cement, dull gold to yellow gold fluorescence, good massive cut, light brown ring cut. Light to medium brown, dark brown in part, very fine lower to very fine upper, moderately sorted, trace glauconite, trace mica, abundant disseminated pyrite, patchy siderite, fair porosity, dull gold fluorescence, good milky yellow streaming cut, light amber ring cut. Black to brown, very fine lower, very fine upper in part, moderate to well sorted, predominately tight, trace patchy disseminated pyrite, abundant siderite, scattered dull gold patchy fluorescence, slow to fair streaming cut, trace light amber ring cut. BP Exploration, Inc. NWE 1-02 NW EILEEN PRUDHOE BAY, ALASKA Core Chip Sample Descriptions 7095' Sandstone: 7098' Siderite: 7101' Sandstone: 7104' Sandstone: 7107' Sandstone: 7110' Sandstone: 7111.7' Sandstone: Dark brown to black, medium brown in pm-t, very fine lower, very fine upper in part, moderately sorted, abundant siderite, predominately tight, light yellow gold patchy fluorescence, slow diffused cut, no ring cut. Dark brown, hard dense, slightly sandy, trace pyrite, free oil on surface, bright yellow fluorescence. Black, tan in part, very fine lower, well sorted, trace glauconite, abundant siderite, trace patchy pyrite, no visible fluorescence, no visible cut. Black, scattered brown, very fine lower, well sorted, abundant pyrite, abundant siderite, tight, slight trace light yellow gold patchy fluorescence, slow diffused milky yellow cut, no ring cut. Medium to dark brown, very fine lower to silty, mOderate to well sorted, slight trace glauconite, scattered trace siderite, trace disseminated pyrite, trace black carbonaceous inclusions, poor to fair porosity, dull yellow gold fluorescence, slow streaming cut, fair diffused cut, light amber ring cut. Medium to dark brown, very fine lower, well sorted, abundant siderite, trace patchy disseminated pyrite, predominately tight, trace dull gold patchy fluorescence, slow yellow gold diffused cut, light amber ring cut. Black to dark brown, very fine lower, silty in part, well to moderately sorted, abundant siderite, predominately tight, trace dull gold patchy fluorescence, slow yellow gold streaming cut, fair yellow gold diffused cut, light amber ring cut. 7111.7' to 7115' not recovered Chips taken in 3' intervals at inner barrel cuts. Core 4/2: 7115' to 7135' Kuparuk C sands 7115' Sandstone: Black to dark brown, very fine lower to silty, moderate to sorted, hard, tight, predominately 95% siderite cement, trace patchy light gold fluorescence, weak light yellow diffused cut, light amber ring cut. 7118' Sandstone: Light to medium brown, black in part, very fine lower to very fine upper, moderate to well sorted, trace glauconite, trace scattered mica flakes, 30% siderite cement, poor to fair porosity, massive light yellow to yellow gold. fluorescence, massive milky yellow diffused cut, light amber to light brown ring cut. 7121' Sandstone: Black to dark gray brown, very fine lower, silty to shaly in part, well sorted, moderately sorted in part, very slight trace glauconite, trace mica, 98% siderite cement, no visible fluorescence, slight trace pin point cut. 7124' Sandstone: Medium brown to black, very fine lower to siltstone, well sorted, slight trace glauconite, 70 % siderite cement, predominately tight, massive yellow gold fluorescence, massive milky yellow cut, light brown ring cut. 7127' Siltstone: Black, dark brown, scattered trace very fine lower sandstone, slight trace glauconite, trace mica, trace small pyrite inclusions, abundant siderite cement, no visible fluorescence, no visible cut. 7130' Sandstone: Brown, light gray to black, very fine lower, very fine upper to silty in part, moderate to poorly sorted, slight trace glauconite, trace mica, scattered trace disseminated pyrite, 50% siderite cement, patchy light gold fluorescence, fair milky yellow streaming cut, slow diffused cut, light amber ring cut. 7133' Sandstone: Dark gray brown, black, very fine lower to silty, shaley in part, moderate to .well sorted, scattered mica flakes, occational trace small black lithic fragments, abundant siderite cement, no visible fluorescence, very weak diffused cut, light amber ring cut. 7135' Shale: Black, slightly silty to sandy, slight trace glauconite, scattered mica flakes, no visible fluorescence, no visible cut. Full Recovery .. 'N~BORS18E DRL FRX ID' HRR 19'¢9 5'$1No.O04 P.iO I~ii'. ,' .... :' coRE RuN E°'G'., I~ I'coR.E.'~." ': ! ;;]i cOMPANY::.: SHARED sERVICES DRILLINGl DEPTH:I'Ni' :" '.i'.." 706;2 ..... FSRMA¥10'N?.i' i i! ~UPARUK Rib!-i:.i:.i-': :::::.i NABORs 18~ ........ D, EP~H:0Uy: '.. ~ 7115 .... DESCRi'PTioN:?. ~: ...... WE'L~N~:¥.::~ N.W. EiLEEN'I~2 " HOL~'siZE:'-.: ...... ': 8,5 "' FT~.~'THJ'S':~RUN~':~.~:. :;~: J DATE:.~: ~:::?:. !~aar.98 ..... ~HOLEA[NGLE::::.L 10DEG - ~PREV.:~0OTAGE:.:-.I 0 s3 BARRE~:SIZE:..:.:.:::.' :: ::: 6 314" X 4-.- - , ,; ,= , , , .. , , LENGTH (~): .;.;; 60 - COREH~D ~ ~. :;'.. ARC 412C3 SUR.~ JN~ER~OBE:~PE:: ~uminum tu~e SERI~:.~:.~'-;.:;'?.;~;~. 1902197 ' ' ' DH-~EM~;;;;;;' 100 EgfloEic~hERf~ COREGUARD/SPRING S~;: :..'::::. :-..;;:':::~ :'..';;: 8 iD,, X 4" ' ~S~X~hG;:.:::.:.. 1D" ........ z ....... : ..... . . , . ;--;~ '';''' '' ' ...... 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' 1' EA CORE~UARD L.O~ER SHOE .... 1' ~'BEARING ........... ..... .,, ~ ,., , 1 ~ UPPER INNER BBL SUB ,., _ ............. ..... - 40 ~ CAps AND CLAMPS ......... ..... ,,, 2'EAINNERTU~'~'~YABI~I~ERS' _ ............... 1 EA BEARING RETAINER . _, ~uStOme~::.Rep:: ::~ I~AyNE STAFFORD') BIL~.,O_~EN' IB.H;In~: · 'NClBORS~.SE DRL FI:IX ID' I, Ii:lR 19'q8 5'29 No.OOZl P.09 COMPANY: SHARED SERVICES Component STABILIZER OUTER TUBE STABILIZER OUTER TUBE iOUTER TUBE I STABILIZER LD ADJUSTING SAFTY JOINT BOX SAFTY JOINT PIN ClRC SUB X OVER SUB NM FLEX COLLAR NM FLEX COLLAR NM FLEX COLLAR X OVER SUB JARS Well Name & No.: NW EII_EEN '1 TYPE ARC 42503 Down Up HT PIN HT BOX HT PIN HT BOX t4T PiN HT BOX HT PIN HT BOX HT PIN HT BOX HT PIN HT BOX HT PIN HT BOX HT PIN HT BOX HT PIN TIW BOX TIW PIN 41/2 IF BOX 4 1/2 PIN 41/2 IF BOX 4 lr2 IF PIN :4 1/2 XH 41/2 XH PIN! 41/2 XH 41/2 XH PIN: 41/2 XH 4 1/2 IF PIN 41/2 XH 41/2 XH PIN 4 t/2 IF BOX 4 1/2 IF PIN 41/2 IF BOX 4 t/2 IF PIN 41/2 IF BOX Rig/Contractor: I Field: NABOR$1,BE, I, NWEILEEN Serial No.. 1902202 Serial No, GaugeOD 8 15/32" 2004 8 1,~r32" 2004 8 15/32" 2OO4 8 15/32" 20O4 2OO4 TSA i BHI Job # ,, Coring BHA No: ' =Dat~:" I Il II 450.~6591 2 16-Mar.88 Location: I' Country: NORTH SLOPE, AK USA Depth oul 7,115 1.42 Fish Neck Length(R) Tolal Length{fi) 2.38 4.00 5,42 26.00 31.42 2.38 2.38 2.38 4.00 35.42 26.00 61.42 4.00 65,42 26.00 91.42 4.00 95.42 3.75 99.17 1.19 100.36 ~ .o4 101.4 2.5 2.5 2.16 103.56 1.39 104,95 30.5S 13 5,53 31.m 166,54 2.52 31.00 197.54 2.8a 200.42 31.o4 231.46 456.76 688.22 :' Sta:bfilzet:':"' '""' STABILIZER STABILIZER STABILIZER Difference: 8 15/32" 815/32" 815/32" STABILIZER .Previous.BHA: ..... Blades RMW RMW RMW RMW ,: :~.~ BHA:.Eeh 0.70 0.70 0.70 0.70 688.22 ... ......... .. .OWei' G&E 5 .. HWDP .ID (1') 19.5 ConneCtionS 41/21F · 11 .~. IF: ;BHAWel¢ht. "In'air. :" Below dara 12 10 · . )BJECTIVE:for'~"hin~i:BHA~ · out :HA REGULUS':'' ": I.I i i i l' :B~kir'HU~lhe' INTEQ'ReP,re',~e','ntatlv'_e:: '.. · ! ,lim Gale , ! _ __ HAROLD PERSON, . NClBORS~SF DI~L Fi:IX 'I']),= HI:IR :i.g'g8 5':54 No.O04 P.il I% · ::. : : .: .... : DEPTH ' NOi' 'R;O:P' ! 'PENETRA"flON RkTr---:, ~'I/HR.'... i": ...... -__O,L~,B&TJNG ::.¢,,,gNDmON~; i:- .... ;: i. ..~R.MATI~.' .. . - . ,. . . . .; . : ! . -:. . . - ........................................... · . . . . ; . . .. ....... . .... : .. -:..: . · ..... i:" FT.. COREO.' ...... .. Min./~ . .: Ft/!tr~' : ' ' ' ' ' :'W.O.B R.P.M : F.P, ATE: .PI~ESS. 'I'O~C3U~· : :'TYPE.... t:J.~:.:~:;..'.:!;o .:.:: :t ' ;°:' : ,':"" -' ~ * - ~-:"-.. ii!~ ~: : ..... 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Wo, ~i~o s i s~nd ..... ' ' ' ' ' '~" ' = , ,, 8 &~ 300 1180 8 7102 40 2. 30.0 J.:'{] .... '.,,o, -:,.,-",' ,,o.o · , I"'::: .... ,I~ !_ 8. ' 85 ' ~"' 1170 ~ .... ,Sand ..,. ...~,~ : . ..,ii '' -] {' : 6 85, 3.11 ' 12=~0 -,.,07 ,,,, ,, ; ~.o' ...:.;~ ~i l~l-'~'i:'~:i "'.,o' ,,o ; 3;1 "¢~o. ,,o, ,, ,,. ,o ,,: ,, ,,,o :;: -* ,, . ~1:_--,;:; l~l~'~ 711 :i. ,o .~o_: ,,, ,,,o . ~,.~ .... 71~ 4, 3 . i ' ~'~'" ii: ~~t u~ ...... ::" lo ___~o ,. J,4o , s,o~ ~ , ::.1 , . ............... 7112 r:,o , .~ e,o.o j~l ~.~J~ ~ '~" J' 10 ...~_ 311 .'~220 s .... s.,,~.. ...... 7113 51 5 ' 12.0 !~i ~ ...... 10 ......... ~ ~11 1220 8 ~__, 7114 S2 .... § 12.0 Ii' '~ , : 10 f)O 311 1240 -_ 7!15 53 .20 .3_0~: ~:i ~ " = ~ .... _gp......._ -- ~11 1240 0 JAME:O . _~.. ,~ ~..1~ ............. · - ~, ~:i' : .... I' ' ' " ::~', ...=............... i--. ' .... ' ---' " 'ii ....... ' .......... i.. - ' ............ __ ' ~ :~ ..................... t " ....---~ l!i ....... !:::.'-., J:: ,, _- '~ iii "~ ........ ' ' .... ili ....... : ......... :.._, t!: - . 1~-, iil ................. ~i¢ -- ..... ........... ,. ID' MI:IR 19'98 5:41 No.004 P.i$ Coring Operations Parameter Sheet- 3/18/98 NWE 1-02: 8-1/2" Core #1. 7062' - 7115.95' (in lbs) Wt on btm: 122K Dropped ball 910 psi PU Wt: 195K Ball on boltem 1170 psi 9:(gl AM SO Wt: 117K Begin coring Torque: 8K Depth' ~/OB "R~'~ P,'essur~ ' SPM" Time Ti,,,; Elal,sezt (fl =md) (klbs) RPM ()}si) SPM hr:min:soc (time/fl) _ i ! · i 7062 4 50 ! 170 ~16' 9:06:00 0 7063 5 50 1170 96 9:07:20 0:01:20 7064 5 5(I ' ' 1160 ' '96 .... 9:(}9:50 (i:02130 706~ 5.1 .7~ ~'~ 1150' ' '97 9:1~:06 0:02:10 7066 5.5 70 1150 96 9:12:37 1'):00:37 7067 5.5 70 ! 150 97 9:13:00 ' 0:00:23 7068 6.3 70 1150 97 9:14:00 0:01:00 7069 4.5-6.3 70 1150 97 9:15:45 0:01:45 __ 7070 5.9-7.5 70 1150 97 9: i 6:42 0:0{!:57 7071 5.5-8.3 " '7'0 1150 ' '97 ..... 9:21:00 0:04:i~ - ....... 7072 7.1 '8.6 70 1150 97 9:24:03 0:03:03 7073 7.3-8.0 70 i 150 97 9:26:i2 0:02:09 7074 7.1-8.0 70 1150 97 9:27:52 0:01:40 7075 6.9-8.2 ' ' "~0' 1180 9'7 9:30;41 0:02:49 7076 7.8-8.5 75 I 180 97 9:34:32 0:03:5 ! 7077 7.2-8.6 75 ...... 1180 97 9:37:(15 0~02:33 7078 7.1-8.8 ..... 75 ' "!'180 97 9:39:12 0:02:~17' _ 7079 TS- ' 85 '" 1180 97 9:40:22 0:61:10 7080 7.2 85 1180 .... 97 "' 9:~2:22 (1:02:00 .... 7081 6.9-8.6 85 1180 97 9:44:14 0:01:52 7082 6.9-7.6 85 1180 97 9:45:48 0:01:34 7083 6.9-7.6 85 1 ! 60 97 9:47:10 0:01:22 7084 6.9-T4 85 116{i 97 9:48:28 0:01:18 7085 6.9-8.1 85' 1160 ..... 9:7 .... 9:4~:47 '0:01:!9 ..... .............. 7086 7.2-8.0 85 ! 160 97 9:50:54 0:01:07 ,. 7087 7.1-9.0 85 I 15{I 97 9:51:54 0:01:00 7088 6.3-7.9 85 ' ! 140 97 9:52:45 0:00:51 7(189 7.1-7.9 85 1140 97 9:53:55 0:01:10 7090 7.1-9.6 85 1130 97 9:56:06 0:02:11 7091 6.0-I0.7 '85 ' 1160 ' ' ' 97 " 9:57:36 0:01:30 ...... , ..... 7092 614-9.I 85 Il(R} 97 ~ ' ' ' 9:58:50 0:01 14 7093 "7'.0-10.685 1160 97 9:59:35 0:00:45 7094 6.5-7.7 85 1160 97 IO:O1:58 (1:02:23 ........ 7(195 7.0-9.8 85 1180 97 10:03:49 0:01:51 7096 6.8-12.2 85 1111 97 10:05:44 0:01:55 '7097" ' i011' ' ~6 II(ff} 97 ., 1 {_1:24.'.1 ! ...... {.!i.l 8:27"' 7098 10 85 1170 97 10:25:28 0:01' 17 7099 9-10.0 80-90 ' '1 '1 ~0 98 10:27:09 0:01:4 ! _ 7100 9-10.0 85 1170 98 10:28:50 0:01:41 7101 9-10.0 85 1170 98 I ('):29:30 0:(81:40 7102 9-10.0 8~ 1170 98 I0:31 :Z~i 0:01:55 l'rt;parcd by BI'X Alaska 3/19/98 Page 1 .NFtBORS~.SE DRL FflX ID' I, lfiR 19'q8 5'42 No.O04 P.14 7103 "-9-10.0 85 Ii70 i 98.,'' 10:33':00' 0:01:35 7104 9-10.0 85 1170 98 10:34:31 0:01:31 7105 9-10.0 85 !17(I 98 _, 10:35:56. 0:01:2.5 7106 9-10.0 85 1170 98 lO:3g:lO 0:02:14 7107 9-10.0 85 1180 98 10:43:35 0:05:25 7108 10 ' ' 85 1220 98 10:46:00 0:62:25 7109 10 88 1230 98 10:54:00 0:08:00 7110 l 0 gg i 220 98 10:57:00-. 0:03:00 7111 9-10.0 85 124.13 97 10:59:14 0:02:14 7il2 i0 85 1220 98 11:01:03 0:01:49 " 7'! i~ 10 85 122(} 98 ! 1:02:30 0:01:27 7114 16 85 1166 "98 I i:07:20 6:04:50 .... 7115 10 "85 "' 1250 97 11:12:00 0:04:40 ':7116 I0 '85 1240 97 11:14:46 0:02:46 ''"')'117 11-12.0 8'.5 1200 ' 97 !1:38:16' ' i)i23:30 , , ,, i ...... :. Prepared by BPX Alaska 3/i 9/98 Page 2 coMPANY: SHARED SERVICES DRILLING DEPTH IN! ' 7'115 FORMATiO~I' KUPAR01~' ' RIG:.. ~ABORS 1SE DEPTHOUT: 7135 DESCRIPTION: WELL No.: .. ,N.W. EILEEN t~2 HOLE SIZE: . . ~ 8.5 F~. THIS RUN: DATE':: ........ ' ~_9-Mar-98 .... HOLEANGLE: ~, 10 DEG PREV,..FOOTAGE: 53 ~T~~;~ 73 - ~EQuiPMENT~' ~ BARREL SIZE: ~' ~' 6 3/4" X 4" -- ~LENGTH (ff):'~ :~: ~;~ .~ 90 COREH~D .' ... ARC 425C3 SURF TEMP 0 ,, ,i~NER~TU~E~PE~; Aluminum tube S~RI~N~:... 1902202 'DHTE~'" 100 . , ~.SHOE/C~CHER:~ C~REG~ARD/SPRING SIZE: ,,,.. - '.. S ID"X4",, SPACING , 1" _. ....... i . · .11 ' COREHEAD:CONDITION::"': 'iR~ 'OR" . '.'.DC' .' ~ 'L~' :~B/S'' .G)16 :':oc'~:~ ..... '~:'R:P[D ...... -'" , · .......... .. . ';;'~;';;:"7~'~:'. ..... BIT CONDITION'RUN ~T~T NEW _ . o ~ ~-~ . . .~ . ;[ .,s ~,~o ...... : LT;. STAB: ~./Yes IBIT END' eR~:INo iCOrlng BHA:lARC425C3 6 314" x 90' HT30CORE BBL ClRC SUB xoV~R. DAFD~T00~.~No IC~I~ ;~::.;':;;;~:;';:'lNo . I.: ', ': ~: ;-:..I~LExC0L~RS'X~V~RHwDP "' ' .... ~BACKGROU'ND: :PA~METERS'::' ,, ,. . ...... - "O~F'BTMs~RiNG. WYs: ":':TORQUE K~ea: ' ' .B~~v~;.P~eas!NC,' ' ' " PR :..: ': : .::Up(Klbt);;:: :-~ 1~ ~F'~YT~' :1. 6 'FLY--Ye... · i 310 ! G~. FLOW~TE':. 310 ..,~;---~'~': "~R~ATINO~(KI~). 130... ~W.~:.:. ! _a.'. pRESsuReiNceeAsE I 3~ I; ps~ oe~~:: 12~ ·-~'.':.'"..::: ~ ' "~WN~lb~2;~:'f.;: lZO .......... : ...... - .... ........ 0'~-~~; ~21° : . .; . ; : ~-UD PROPERTIES i ..... ...:%H20/QiL :: .... VISC'; :.':' ":':';:' . ....... :: :~:....... :....:: :..'; :. ............. : . : · : .: : . :.:. .: . : .. . . : · . .. . :....:~..:::~:.:::.::.'; :...:.:.'.. ? ~:.. ...:. ': :.: .... , ..... : . ; .... . ..... :~: ..... :.. .:.. :: .. . ' -~O 6%KCL 1~ . , 1,1:3 .... 47: , 4~ ~12 . ,7'O~HP 0.25 ,. 1~... ~TIMINGS' ':.'.:"~':'~". .... {24HO. )':':,.:.: :__.:, -_:'...:: ' ~' '_.. :~. :. ::" :':--:.-. .:,,:..-~: .~ .... ::: ~' ' '"PIC~"UP':.': ....... ': :STARTIN' ":' '.:'.:DROP :CORING .- p.O.O,H...: ~ ;....:~:::.:~,Y~;.:.~:~:.~: ~... ' "~' '.:' BBL' ' "::" ' HO~E ": .:BALL .. · .. SERVICEBBL :: .... .:.~-STOBqR..UU~ .' . .,, .... . . : .... :~ ...... ?,. ,.. : : .... '.~. :.: ....... , ....... ~ ........ · START(. : ....... :'.. , ..... ........ . . . ......' ...... :..: ; .. : , , , _ .: . , , ...... · :.: ~, . ,, ~ , . . .- ~. - ~-: '1 I"" I . ' " . ' ., '~:~':':'.~::..:: ':8 .:..;. .:C0n'%ctl0n: ~:l'~'~':':1'~'1': ~':2'' I: :' ~'3": ~'~'~" -. ..... ~' ": ~': ":S,D'dpth ' ' . ..... ' ...... J ~ ...... ,.. :~ , ~ .. ~ :.: Co[i~g.~ ~ :: Fee[R~overed:~ ..: .:.~ ~ ~ ........... ~' : . :. " ... .... ': . .: . .:.¥... :::.: ........ ~..:..:.;... :s.~.:.: ::.~-~:. : ' · ............. HOUr.'. ' ....... ;:. ........... ~ ...................... , _. . . . ?,., . ~..: ...: · :.,, ::.1~.~.: .~ : ....,;:~; . .. ~ ' : ' ' ... .... ...... ' ......... 7115 7135 20 7.32 ,~..7:~ 20.1 '10t ~ '~:~";~ ~~'G::/ ~ ::[ SLOW PENAT~TI~N .... =SPARE PARTS' USE~ ~ ARC425C3 ~1902202 ~' 3 EA ALUMINUM INNER BBLS 1 EA COREGUARD LOWER SHOE 1 EA UPPER iNNER BBL SUB , . ' 15 EA CAPS AND C~MPS "' 2'LA INNER TUBE STABILIZERS 1 EA SPRING cORE CATCH~,R . d~0Mer R~p' JWAYNE STACFORD/B":L OWEN " .I~H:~o~ R%: .I,~,¢,' <.';..,,.,'~'~=~.r.)~,,~.[~O~ ... cust0mer::~ SERVICES ~ SIZe: ~ABOR_S 18E __ En~neer: 1'~. ~7~~ '!':; .i.DEPTHi:.;'i.; :::,: ~'i;~: ~!' ':. 250P::CORE'BARREL'I'- . . Dep~? Oe'l~{ll' .~:"Size n:nei:Iube-..Catcher' '.!:From'! ,":';.T~" .. :.i,::.i... ...... 7062 6 3/4" X 4" Aluminum SPRING 7115 7135 6 3/4" X 4" Aluminum SPRING .. · .. RecoveW: .. · . . 13-Mar-98 20-Mar-98 5 1/2" X 10" KCL GEL 2.11 25.11 7.32 2.73 ~S~,,^~:~0':.::.'~,: ': :' 'S~;;; ..;.;: :::;. i':. '.'W,'~.' :.."'? .i' -: ~. ·Per:Hour' 1902 !9'2' 8 1/2" X 4" ARC 412C3 25.12 ;~ 8 112" X4" ARC 425C3 ' 2.73 NEW 2% NEW 5% WORN ~'~.b~ · R.PM F.RAlt~ PRES~ TORQUE : .":' ~ '.:'..:.: [ ~t~. op~ ~ P,~ ~ ........ Z~O-''' 1~ 8 SIL~ S~LE ~--~ - ~--' ~ ~ SIL~ SH~E ~4_ . ~_ ............. ' - ~~' ~ 310 1270 ~ ~ SHALE 16 mo 310 12~ 6 ~ SHOE 16. ao ~10 12T0 7 ~L~ SHALE 18' ~ 310 12~ 7 ~L'~ ~ALE .. 18 ~ , ,.3! 0 12~ 7 ~L~ ~ALE.., 18 ~ 310 1270 7 16 ~ ?0 1270 T ~L~ ~ALE 1~ ~ 310 ~2~ 7 ~L~ t0 ~ 3~0 1270 7 ~L~ ~ALE _ 1~ 1~ 3t0 1270, . 8 9l~ SHAL~. 12 1~ 310 12~ ~ SIL~S~LE 12 1~ 310 1270 7 SIL~ ~ALE ,,, , 1~ _ 3~ ___ 1270 7 ~L~ SHOE ,. ....... . ,, ........... __ . ... ,., . ~1 , , I ..... FT.' CORc-=D. Min/Ft Ft/Hr~, . :!'.': . '~'.t':~:';' ' : ; · ..... : :: ::.-'.':: "~.: ' {ii 7'~'~. ~ 2,= 2.~ 7117 2 , 25 ~.4 711g 4 13.~ { 4.~ /. .... .,71~1 ~ 28 21__ 7 {~ 7 ; 41 ' 1.5 '~ ~" 71~4 g ' 1~ 4.3 .2. ~-- ---~ ~ ~'~ ~127 12 !4.~., 4.S .... 7120 13 ~ 2.0 71~ '-~ ' . 22 .'2.7 ' 7~_ 16 12 5.0 ":~ 7132 17 23 2.~ '~ ~: ~ 7!35 "'~' ~i~ ~ . ~._. .... , ....{~ ..... .......... }~ .~, ~ ~.. ~_ , ~.~~ , : .... , , =~: ~.. i[~ ..... il" -~ - ~ ..... , ..... . .. [: ~ .... ........... I[ .__. .... j[ ..... ..... ;: ...... 4,. ..... - i~] ..... ..... 439 arameter het- 3 18/ 8 Wt.,; (klbs) NWE 1-02 Coring operations, Core #2 Pick up 160 Company Man's Log Slack off 120 Dropped Bali 910 psi 99 SPM 5' 15 Rotate 130 Ball Seated 1141) psi 09 SPM ' 5:3{) Torqu,e 7-8.0 'Depth WeB RPM Pressure SPM Time Elapsed (ft -md) (klbs) RPM (psi) SPM ,_ (rain,/ft) 7116 8.1 t.0 ' 62 1300 97 2,1 7117 10.5-11 63 1290 97 25 _ 7 t i'8 13 67 li60 97 t 3 7¥ '19 14 69 1240 98 13 7120 14 '69 1250 98 21, 712i' 14 69 1260 98 28 7122 '- 14 ' 80 1270 98 4 7123 14 64 1270 98 ,26 7124 t4 81 1250 9,8 14 7125 14 80 1260 98 9 ,,, 7126 15 8 ! '1260 98 8 7127 16 81 1260 98 14 - 7128 15 81 1270 98 23 7'1.29 16 8 t '1260 ,98 22 '7130 16 8t 1260 98 22 ~ 713'l ' ' 10 81 1260 98 12 7132 10 8 t 1260 98 23 _ 7133 10-15.0 84-100 1270 98 23 7134 t2 t00 1250 98 47 _ 7135 12 100 1270 98 ,. 31 · l~rcparcd by BPX Alaska Pttgc 3 Operator BP Exploration Performance Enquiry Report Date 20:41, 06 May 98 Formation Integrity Test for NWE 1-02 Page I The analysis is from - 02:00, 13 Mar 98 - to - 02:00, 13 Mar 98 Programs in Result Table: NWE 1-02 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) Depth MDR Hole Size MDR ~'~ 1-02 Event 02:00, 13 Mar 98 02:00, 13 Mar 98 0 hr 0 min Obtained leak off 14.7 3250.0 8-1/2 Anadrill Client: BP Exploration Field: Prudhoe Bay Well Name: NWE 1-02 APl number: 50-029-22865 Job Number: 40002297 Rig: NABORS 18E County: NSB State: AK Survey/Calculations Calc method for positi¢ Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum Depth reference Drill Floor, GL above Permanent KB above Permanent DF above Permanent Vertical section ori~lin Latidude (+N/S-): Departure (+E/W-): Azim from rotary table to target: MSL 75.70 FT 46.70 FT 77.20 FT 75.70 FT +70.35050641 -149.32615020 42.90 degrees Schlumber~ler ANADRILL Survey Report Seq Measured Incl Azimuth Course # Depth angle angle length /ft/ /de~l/ /de~/ /ft/ 1 0.00 0.00 0.0 0.0 2 116.49 0.10 19.9 116.5 3 215.54 0.15 36.8 99.0 4 308.83 0.46 55.3 93.3 5 401.11 0.77 43.5 92.3 6 492.93 1.50 37.5 7 582.39 2.58 35.0 8 673.67 4.34 35.6 9 770.32 7.22 38.2 10 861.60 9.61 42.0 11 952.80 11.70 42.4 12 1044.63 14.21 42.4 13 1137.45 16.83 43.1 14 1230.44 18.47 42.2 15 1323.01 18.92 43.4 16 1416.11 20.41 43.1 17 1507.04 21.81 40.4 18 1602.17 21.57 40.8 19 1695.24 22.36 38.7 20 1787.59 22.60 40.4 91.8 89.5 91.3 96.6 91.3 91.2 91.8 92.9 92.9 92.6 93.1 90.9 95.2 93.0 92.4 SURVEY REPORT Spud Date: Last survey date: Total accepted surveys: MD of first survey: MD of last survey: RECEIVED APR 7 1998 BPXA PDC 09-MaF98 21-Ma~98 81 116.49 7505.05 Geomagnetic data Magnetic Model: Magnetic Date: Magnetic field strength: Magnetic dec (+E/W-): Magnetic Dip: FT BGGM 1996 Vemion 35794.0O 1146.50 HCNT 27.99 degrees 80.69 degrees MWD Survey Reference Cdteria Reference G: 1002.68 mGal Reference H: 1145.87 HCNT Reference Dip: 80.68 degrees Tolerance G: 4.00 mGal Tolerance H: 6.00 HCNT Tolerance Dip: 0.30 degrees Correction Magnetic dec (+E/W-): 27.859 Grid convergence (+E/W-): 0.00 Total az corr (+E/W-): 27.859 TVD Vertical Displacement Total at Azm depth section +N/S- +E/W- displacement /ft1 /ftl /ft/ (it/ /it/ (deg/ 0.00 0.00 0.00 0.00 0.00 0.00 116.50 0.09 0.10 0.03 0.10 19.90 215.50 0.30 0.28 0.14 0.31 26.78 308.80 0.79 0.59 0.52 0.79 41.46 401.09 1.77 1.25 1,25 1.77 45.04 degrees degrees degrees DLS (deg/ 100f/ 0.00 0.09 0.06 0.34 0.36 492.87 3.58 2.65 2.41 3.58 42.25 0.80 582.32 6.75 5.23 4.28 6.76 39.27 1.21 673.45 12.21 9.73 7.47 12.26 37.52 1.93 769.55 21.89 17.47 13.35 21.99 37.39 2.99 859.86 35.23 27.64 22.00 35.33 38.52 2.69 949.48 52.09 40.13 33.33 52.17 39.71 2.29 1038.94 72.66 55.33 47.21 72.73 40.47 2.73 1128.44 97.52 73.57 64.09 97.57 41.06 2.83 1216.96 125.68 94.29 83.16 125.73 41.41 1.79 1304.68 155.36 116.07 103.33 155.40 41.68 0.64 1392.35 186.69 138.89 124.80 186.72 41.94 1.60 1477.15 219.41 163.32 146.57 219.45 41.91 1.87 1565.61 254.57 190.04 169.47 254.62 41.73 0.30 1651.86 289.30 216.78 191.70 289.39 41.49 1.20 1737.23 324.56 244.02 214.20 324.69 41.28 0.75 Page1 0 G. N A,L Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD # Depth angle angle length depth /ft) (de~) (de¢l (ft) (ft/ 21 1878.88 22.44 40.2 91.3 1821.57 22 1972.53 22.18 41.4 93.6 1908.17 23 2063.35 22.39 41.6 90.8 1992.18 24 2156.04 22.17 41.6 92.7 2077.96 25 2248.89 23.29 42.2 92.9 2163.65 26 27 28 29 3O 2341.60 24.26 42.1 92.7 2433.74 25.53 41.2 92.1 2528.08 26.33 42.5 94.4 2619.93 27.93 42.4 91.8 2712.19 27.77 42.7 92.3 31 32 33 34 35 2756.92 27.57 42.2 44.7 2857.73 27.79 41.6 100.8 2958.92 28.02 41.2 101.2 3052.16 27.83 40.7 93.3 3144.68 27.79 41.2 92.5 36 37 38 39 4O 3236.63 27.45 40.8 91.9 3329.85 28.10 39.4 93.3 3423.34 28.79 38.5 93.4 3516.09 28.11 37.9 92.8 3608.23 28.39 37.4 92.1 41 42 43 44 45 3702.68 27.28 44.9 94.5 3797.08 26.68 44.5 94.4 3891.08 26.13 44.0 94.0 3983.14 26.87 46.8 92.0 4075.96 26.81 47.4 92.9 46 47 48 49 5O 4170.23 26.81 47.2 94.2 4263.90 27.05 46.8 93.7 4358.81 27.11 45.9 94.9 4451.11 27.83 45.9 92.3 4545.28 28.22 46.2 94.2 51 52 53 54 55 4637.93 28.31 45.0 92.6 4730.80 28.26 44.8 92.9 4823.20 28.39 44.9 92.4 4914.55 28.59 44.4 91.4 5009.22 28.67 44.5 94.6 56 57 58 59 6O 5103.59 28.46 43.2 94.4 5198.68 28.27 43.0 95.1 5289.92 28.11 42.1 91.2 5383.61 27.66 41.6 93.7 5478.32 27.17 41.4 94.7 61 62 63 64 65 5569.90 27.06 39.9 91.6 5663.61 27.06 41.2 93.7 5756.15 26.78 44.8 92.6 5849.01 26.35 44.5 92.8 5941.67 25.80 43.9 92.7 66 67 68 69 6035.59 25.22 44.1 93.9 6128.72 24.12 42.3 93.1 6221.27 22.60 43.1 92.60 6316.12 20.31 41.0 94.80 Ve~ical Displacement section +N/S- +E/W- (ft1 Iftl /ft/ 359.50 270.69 236.81 395.00 297.59 260.03 429.42 323.38 282.84 464.56 349.66 306.18 500.45 376.37 330.15 Total at Azm DLS displacement (d eg/ /itl /deg/ IOOf) 359.66 41.18 o.19 395.19 41.15 0.56 429.62 41.17 0.25 464.76 41.21 0.24 500.66 41.26 1.23 2248.48 537.82 404.08 355.23 538.02 41.32 2332.02 576.58 433.05 380.99 576.79 41.34 2416.92 617.85 463.79 408.53 618.07 41.38 2498.61 659.71 494.68 436.79 659.92 41.44 2580.22 702.82 526.45 465.94 703.03 41.51 1.05 1.44 1.04 1.74 0.23 2619.81 2709.07 2798.51 2880.94 2962.76 723.58 541.76 479.95 723.78 41.54 0.69 770.40 576.62 511.22 770.61 41.56 0.35 817.74 612.14 542.54 817.97 41.55 0.29 861.41 645.14 571.18 861.66 41.52 0.32 904.54 677.74 599.47 904.81 41.49 0.26 3044.19 947.12 709.89 627.42 947.42 41.47 3126.74 990.54 743.15 655.42 990.88 41.41 3208.86 1034.93 777.75 683.38 1035.33 41.30 3290.45 1078.99 812.49 710.72 1079.47 41.18 3371.58 1122.39 847.00 737.35 1122.99 41.04 3455.18 1166.42 880.20 766.29 1167.03 41.04 3539.30 1209.22 910.64 796.41 1209.77 41.17 3623.49 1251.01 940.59 825.59 1251.52 41.27 3705.83 1292.01 969.39 854.82 1292.45 41.41 3788.72 1333.84 997.94 885.54 1334.19 41.58 0.42 0.99 0.87 0.79 0.40 3872.80 1376.21 1026.76 916.77 3956.34 1418.53 1055.70 947.80 4040.83 1461.66 1085.52 979.06 4122.73 1504.17 1115.15 1009.63 4205.88 1548.37 1145.87 1041.50 3.88 0.66 0.63 1.58 0.30 1376.48 41.76 0.10 1418.74 41.92 0.32 1461.82 42.05 0.44 1504.30 42.16 0.78 1548.46 42.27 0.44 4287.44 1592.17 1176.55 1072,83 1592.24 42.36 4369.25 1636.16 1207.73 1103.90 1636.22 42.43 4450.58 1679.98 1238.81 1134.82 1680.02 42.49 4530.92 1723.55 1269.83 1165.46 1723.59 42.55 4613.95 1768.87 1302.18 1197.20 1768.89 42.59 0.62 0.12 0.15 0.34 0.10 4696.86 1814.00 1334.73 1228.47 4780.54 1859.18 1367.72 1259.34 4860.92 1902.26 1399.46 1288.48 4943.74 1946.07 1432.10 1317.72 5027.81 1989.66 1464.76 1346.61 1814.02 42.63 0.70 1859.19 42.64 0.22 1902.28 42.64 0.50 1946.10 42.62 0.54 1989.69 42.59 0.53 5109.34 2031.38 1496.43 1373.80 2031.41 42.55 5192.79 2073.96 1528.82 1401.51 2074.01 42.51 5275.36 2115.87 1559.47 1430.09 2115.92 42.52 5358.36 2157.35 1588.99 1459.26 2157.39 42.56 5441.62 2198.09 1618.20 1487.66 2198.12 42.59 5526.37 2238.52 1647.29 1515.76 5610.97 2277.37 1675.61 1542.36 5695.98 2314.09 1702.59 1567.25 5784.21 2348.75 1728.32 1590.50 0.76 0.63 1.79 0.49 0.66 2238.55 42.62 0.62 2277.40 42.63 1.43 2314.11 42.63 1.68 2348.78 42.62 2.55 Page 2 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azm DLS # Depth angle angle length depth section +N/S- +E/W- displacement (deg/ /ftl Ide~/ (de~/ /ft) /ft/ /ft) (ft) /fi/ tftl (deg/ 100fl 70 6409.09 18.85 41.7 93.00 5871.83 2379.90 1751.72 1611.08 2379.94 42.61 1.59 71 6502.72 18.11 41.0 93.60 5960.60 2409.56 1773.98 1630.69 2409.60 42.59 0.83 72 6596.11 15.37 41.6 93.40 6050.03 2436.45 1794.20 1648.43 2436.49 42.58 2.94 73 6689.61 13.90 37.1 93.50 6140.50 2460.01 1812.43 1663.43 2460.06 42.55 1.99 74 6783,21 13.50 35.6 93.60 6231.44 2482.03 1830.28 1676.57 2482.10 42.49 0.57 75 6878.29 11.48 38.6 95.10 6324.28 2502.48 1846.70 1688.94 2502.56 42.45 2.23 76 6967.36 9.75 44.0 89.1 6411.86 2518.87 1859.06 1699.72 2518.95 42.44 2.24 77 7065.11 9.81 43.0 97.7 6508.14 2535.47 1871.10 1711.1 4 2535.55 42.44 0.18 78 7165.65 9.96 42.1 100.5 6607.14 2552.72 1883.81 1722.80 2552.80 42.44 0.21 79 7258.62 9.75 41.7 93.0 6698.77 2568.63 1895.65 1733.44 2568.71 42.44 0.24 80 7352.6 9.42 42.8 94.0 6791.46 2584.28 1907.24 1743.96 2584.37 42.44 0.40 81 7445.71 8.83 42.6 93.1 6883.38 2599.05 1918.09 1753.97 2599.13 42.44 0.63 82 7505.05 8.74 41.6 59.3 6941.98 2608.10 1924.81 1760.04 2608.19 42.44 0.30 Projected 7583.00 8.74 41.6 78.0 7019.08 2619.95 1933.67 1767.91 2620.04 42.44 0.00 Page 3 BP EXPLO~T!O~{ . PBU / NWE 1-02 500292286500 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/19/98 DATE OF SURVEY: 031198 PAGE I MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AKEI80159 KELLY BUSHING ELEV. = 77.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -77.20 0 0 N .00 E .00 .00N 207.00 207.00 129.80 0 7 N 21.78 W .06 .21N 298.40 298.40 221.20 0 24 N 74.59 E .48 .39N 390.60 390.59 313.39 0 51 N 53.29 E .54 .89N 482.10 482.08 404.88 1 17 N 38.49 E .55 2.10N .00E .00 .08W .10 .19E .42 1.06E 1.38 2.25E 3.08 572.70 572.62 495.42 2 22 N 31.87 E 1.23 666.26 666.03 588.83 4 2 N 34.69 E 1.78 760.20 759.55 682.35 6 30 N 37.29 E 2.64 851.70 850.16 772.96 9 25 N 40.11 E 3.21 943.30 940.23 863.03 11 26 N 41.82 E 2.24 4.50N 3.88E 5.94 8.86N 6.78E 11.11 15.82N 11.89E 19.68 25.67N 19.86E 32.32 38.18N 30.75E 48.90 1034.80 1029.43 952.23 14 15 N 41.86 E 3.07 1128.10 1119.38 1042.18 16 28 N 42.75 E 2.39 1221.20 1208.15 1130.95 18 33 N 42.35 E 2.26 1314.30 1296.31 1219.11 18 54 N 42.96 E .42 1406.30 1382.95 1305.75 20 22 N 41.65 E 1.67 53.34N 44.32E 69.24 71.60N 60.96E 93.95 92.25N 79.90E 121.97 114.24N 100.16E 151.87 137.11N 120.96E 182.78 1501.02 1471.25 1394.05 22 1 N 40.71 E 1.78 1595.60 1559.09 1481.89 21 30 N 39.00 E .86 1688.90 1645.62 1568.42 22 23 N 40.39 E 1.09 1782.20 1731.80 1654.60 22 41 N 40.84 E .37 1873.90 1816.45 1739.25 22 32 N 42.14 E .57 162.90N 143.51E 217.02 189.82N 165.99E 252.04 216.64N 188.27E 286.86 243.79N 211.54E 322.59 270.20N 234.90E 357.84 1965.35 1901.10 1823.90 21 54 N 41.91 E .71 2056.70 1985.69 1908.49 22 28 N 40.73 E .79 2150.00 2072.00 1994.80 22 9 N 42.42 E .77 2156.00 2077.55 2000.35 22 25 N 41.96 E 5.37 2243.20 2157.87 2080.67 23 22 N 42.26 E 1.10 295.89N 258 . 06E 392.42 321.80N 280.83E 426.90 348.30N 304.34E 462.31 349.99N 305.86E 464.59 375.16N 328.62E 498.52 2335.60 2242.34 2165.14 24 26 N 41.12 E 1.25 2427.90 2326.04 2248.84 25 25 N 42.07 E 1.16 2523.30 2411.93 2334.73 26 10 N 42.64 E .83 2615.90 2494.38 2417.18 27 56 N 43.24 E 1.93 2707.40 2575.20 2498.00 27 58 N 42.40 E .43 403.13N 353.51E 535.95 432.22N 379.34E 574.84 462.90N 407.32E 616.36 493.73N 436.02E 658.49 525.19N 465.18E 701.38 2712.30 2579.53 2502.33 27 55 N 41.96 E 4.31 2728.40 2593.74 2516.54 28 8 N 43.29 E 4.11 526.90N 466.72E 703.68 532.46N 471.84E 711.24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF RECEIVED THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 711.44 FEET AT NORTH 41 DEG. 32 MIN. EAST AT MD = 2728 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 42.90 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 2,728.40' MD BPXA PD( O'R'IGt.N,A,L SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORA. TION PBU / NWE 1-02 500292286500 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/19/98 DATE OF SURVEY: 031198 JOB NUMBER: AKEI80159 KELLY BUSHING ELEV. = 77.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -77.20 1000.00 995.62 918.42 2000.00 1933.25 1856.05 2728.40 2593.74 2516.54 .00 N .00 E .00 47.19 N 38.81 E 4.38 4.38 305.51 N 266.69 E 66.75 62.37 532.46 N 471.84 E 134.66 67.91 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ENTIAL PAGE BP EXPLO~TIOK ?BU / NWE i-02 500292286500 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/19/98 DATE OF SURVEY- 031198 JOB NUMBER: AKEI80159 KELLY BUSHING ELEV. = 77.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -77.20 .00 N .00 E .00 77.20 77.20 .00 .00 N .00 E .00 .00 177.20 177.20 100.00 .15 N .06 W .00 .00 277.20 277.20 200.00 .35 N .05 E .00 .00 377.21 377.20 300.00 .77 N .90 E .01 .01 477.22 477.20 400.00 2.02 N 2.18 E .02 .02 577.28 577.20 500.00 4.66 N 3.98 E .08 .06 677.46 677.20 600.00 9.51 N 7.23 E .26 .18 777.98 777.20 700.00 17.49 N 13.18 E .78 .52 879.11 877.20 800.00 29.10 N 22.75 E 1.91 1.14 981.10 977.20 900.00 44.05 N 36.00 E 3.90 1.99 1084.13 1077.20 1000.00 62.48 N 52.53 E 6.93 3.03 1188.55 1177.20 1100.00 84.56 N 72.90 E 11.35 4.42 1294.10 1277.20 1200.00 109.45 N 95.70 E 16.90 5.54 1400.16 1377.20 1300.00 135.51 N 119.54 E 22.96 6.07 1507.43 1477.20 1400.00 164.72 N 145.08 E 30.23 7.27 1615.07 1577.20 1500.00 195.36 N 170.48 E 37.87 7.63 1723.05 1677.20 1600.00 226.55 N 196.70 E 45.85 7.99 1831.40 1777.20 1700.00 258.09 N 223.99 E 54.20 8.35 1939.59 1877.20 1800.00 288.74 N 251.64 E 62.39 8.19 2047.52 1977.20 1900.00 319.14 N 278.54 E 70.32 7.93 2155.63 2077.20 2000.00 349.90 N 305.77 E 78.43 8.11 2264.25 2177.20 2100.00 381.34 N 334.23 E 87.05 8.63 2373.89 2277.20 2200.00 415.06 N 363.93 E 96.69 9.63 2484.60 2377.20 2300.00 450.34 N 395.75 E 107.40 10.72 2596.45 2477.20 2400.00 487.09 N 429.78 E 119.25 11.85 2709.66 2577.20 2500.00 525.99 N 465.88 E 132.46 13.21 2728.40 2593.74 2516.54 532.46 N 471.84 E 134.66 2.20 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Anadrill SURVEY REPORT Client: BP Exploration Field: Prudhoe Bay Well Name: NWE 1-02 APl number: 50-029-22865 Job Number: 40002297 Rig: NABORS 18E County: NSB State: AK Survey Calculations Calc method for positk Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum MSL Depth reference Drill Floor, 75.70 FT GL above Permanent 46.70 FT KB above Permanent 77.20 FT DF above Permanent 75.70 FT Vertical section origin Latidude (+N/S-): Departure (+E/W-): +70.35050641 -149.32615020 Azim from rotary table to target: 42.90 degrees Schlumber~ler ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD # Depth angle angle length depth /fit /deg/ Ideg/ Irt/ /it/ 1 0.00 0.00 0.0 0.0 0.00 2 116.49 0.10 19.9 116.5 116.50 3 215.54 O. 15 36.8 99.0 215.50 4 308.83 0.46 55.3 93.3 308.80 5 401.11 0.77 43.5 92.3 401.09 6 492.93 1.50 37.5 91.8 7 582.39 2.58 35.0 89.5 8 673.67 4.34 35.6 91.3 9 770.32 7.22 38.2 96.6 10 861.60 9.61 42.0 91.3 11 952.80 11.70 42.4 91.2 12 1044.63 14.21 42.4 91.8 13 1137.45 16.83 43.1 92.9 14 1230.44 18.47 42.2 92.9 15 1323.01 18.92 43.4 92.6 16 1416.11 20.41 43.1 93.1 17 1507.04 21.81 40.4 90.9 18 1602.17 21.57 40.8 95.2 19 1695.24 22.36 38.7 93.0 20 1787.59 22.60 40.4 92.4 Spud Date: Last survey date: Total accepted surveys: MD of first survey: MD of last survey: Geomagnetic data Magnetic Model: Magnetic Date: Magnetic field strength: Magnetic dec (+E/W-): Magnetic Dip: RECEIVED 09-MaF98 21-Ma~98 81 116.49 FT 7505.05 FT BGGM 1996 Version 35794.00 1146.50 HCNT 27.99 degrees 80.69 degrees MWD Survey/Reference Criteda Reference G: Reference H: Reference Dip: Tolerance G: Tolerance H: Tolerance Dip: 1002.68 mGal 1145.87 HCNT 80.68 degrees 4.00 mGal 6.00 HCNT 0.30 degrees Correction Magnetic dec (+E/W-): 27.859 Grid convergence (+E/W-): 0.00 Total az corr (+E/W-): 27.859 Vertical Displacement Total at Azm section +N/S- +E/W- displacement Ift/ /ft/ (ft/ /it/ (deg/ 0.00 0.00 0.00 0.00 0.00 0.09 0.10 0.03 0.10 19.90 0.30 0.28 0.14 0.31 26.78 0.79 0.59 0.52 0.79 41.46 1.77 1.25 1.25 1.77 45.04 degrees degrees degrees DLS (deg/ 100ft 0.00 0.09 0.06 0.34 0.36 492.87 3.58 2.65 2.41 3.58 42.25 0.80 582.32 6.75 5.23 4.28 6.76 39.27 1.21 673.45 12.21 9.73 7.47 12.26 37.52 1.93 769.55 21.89 17.47 13.35 21.99 37.39 2.99 859.86 35.23 27.64 22.00 35.33 38.52 2.69 949.48 52.09 40.13 33.33 52.17 39.71 2.29 1038.94 72.66 55.33 47.21 72.73 40.47 2.73 1128.44 97.52 73.57 64.09 97.57 41.06 2.83 1216.96 125.68 94.29 83.16 125.73 41.41 1.79 1304.68 155.36 116.07 103.33 155.40 41.68 0.64 186.69 138.89 124.80 186.72 41.94 1.60 219.41 163.32 146.57 219.45 41.91 1.87 254.57 190.04 169.47 254.62 41.73 0.30 289.30 216.78 191.70 289.39 41.49 1.20 324.56 244.02 214.20 324.69 41.28 0.75 1392.35 1477.15 1565.61 1651.86 1737.23 Page 1 Schlumberger ANADRILL Survey/Report Seq Measured Incl Azimuth # Depth angle angle /ft) /de~/ /de~) 21 1878.88 22.44 40.2 22 1972.53 22.18 41.4 23 2063.35 22.39 41.6 24 2156.04 22.17 41.6 25 2248.89 23.29 42.2 26 2341.60 24.26 42.1 27 2433.74 25.53 41.2 28 2528.08 26.33 42.5 29 2619.93 27.93 42.4 30 2712.19 27.77 42.7 31 2756.92 27.57 42.2 32 2857.73 27.79 41.6 33 2958.92 28.02 41.2 34 3052.16 27.83 40.7 35 3144.68 27.79 41.2 36 3236.63 27.45 40.8 37 3329.85 28.10 39.4 38 3423.34 28.79 38.5 39 3516.09 28.11 37.9 40 3608.23 28.39 37.4 41 3702.68 27.28 44.9 42 3797.08 26.68 44.5 43 3891.08 26.13 44.0 44 3983.14 26.87 46.8 45 4075.96 26.81 47.4 46 4170.23 26.81 47.2 47 4263.90 27.05 46.8 48 4358.81 27.11 45.9 49 4451.11 27.83 45.9 50 4545.28 28.22 46.2 51 4637.93 28.31 45.0 52 4730.80 28.26 44.8 53 4823.20 28.39 44.9 54 4914.55 28.59 44.4 55 5009.22 28.67 44.5 56 5103.59 28.46 43.2 57 5198.68 28.27 43.0 58 5289.92 28.11 42.1 59 5383.61 27.66 41.6 60 5478.32 27.17 41.4 61 5569.90 27.06 39.9 62 5663.61 27.06 41.2 63 5756.15 26.78 44.8 64 5849.01 26.35 44.5 65 5941.67 25.80 43.9 66 6035.59 25.22 44.1 67 6128.72 24.12 42.3 68 6221.27 22.60 43.1 69 6316.12 20.31 41.0 Course length 91.3 93.6 90.8 92.7 92.9 TVD depth 1821.57 1908.17 1992.18 2077.96 2163.65 Vertical Displacement section +N/S- +E/W- /ftl /ftl /ft/ 359.50 270.69 236.81 395.00 297.59 260.03 429.42 323.38 282.84 464.56 349.66 306.18 500.45 376.37 330.15 Total at Azm D LS displacement (deg/ /ft) /dog/ 100f/ 359.66 41.18 0.19 395.19 41.1 5 0.56 429.62 41.17 0.25 464.76 41.21 0.24 500.66 41.26 1.23 92.7 2248.48 537.82 404.08 355.23 538.02 41.32 92.1 2332.02 576.58 433.05 380.99 576.79 41.34 94.4 2416.92 617.85 463.79 408.53 618.07 41.38 91.8 2498.61 659.71 494.68 436.79 659.92 41.44 92.3 2580.22 702.82 526.45 465.94 703.03 41.51 44.7 100.8 101.2 93.3 92.5 1.05 1.44 1.04 1.74 0.23 2619.81 2709.07 2798.51 2880.94 2962.76 723.58 541.76 479.95 723.78 41.54 0.69 770.40 576.62 511.22 770.61 41.56 0.35 817.74 612.14 542.54 817.97 41.55 0.29 861.41 645.14 571.18 861.66 41.52 0.32 904.54 677.74 599.47 904.81 41.49 0.26 91.9 3044.19 947.12 709.89 627.42 947.42 41.47 93.3 3126.74 990.54 743.15 655.42 990.88 41.41 93.4 3208.86 1034.93 777.75 683.38 1035.33 41.30 92.8 3290.45 1078.99 812.49 710.72 1079.47 41.18 92.1 3371.58 1122.39 847.00 737.35 1122.99 41.04 94.5 3455.18 1166.42 880.20 766.29 1167.03 41.04 94.4 3539.30 1209.22 910.64 796.41 1209.77 41.17 94.0 3623.49 1251.01 940.59 825.59 1251.52 41.27 92.0 3705.83 1292.01 969.39 854.82 1292.45 41.41 92.9 3788.72 1333.84 997.94 885.54 1334.19 41.58 0.42 0.99 0.87 0.79 0.40 94.2 3872.80 1376.21 1026.76 916.77 93.7 3956.34 1418.53 1055.70 947.80 94.9 4040.83 1461.66 1085.52 979.06 92.3 4122.73 1504.17 1115.15 1009.63 94.2 4205.88 1548.37 1145.87 1041.50 3.88 0.66 0.63 1.58 0.30 1376.48 41.76 0.10 1418.74 41.92 0.32 1461.82 42.05 0.44 1504.30 42.16 0.78 1548.46 42.27 0.44 92.6 4287.44 1592.17 1176.55 1072.83 1592.24 42.36 92.9 4369.25 1636.16 1207.73 1103.90 1636.22 42.43 92.4 4450.58 1679.98 1238.81 1134.82 1680.02 42.49 91.4 4530.92 1723.55 1269.83 1165.46 1723.59 42.55 94.6 4613.95 1768.87 1302.18 1197.20 1768.89 42.59 4696.86 1814.00 1334.73 1228.47 4780.54 1859.18 1367.72 1259.34 4860.92 1902.26 1399.46 1288.48 4943.74 1946.07 1432.10 1317.72 5027.81 1989.66 1464.76 1346.61 0.62 0.12 0.15 0.34 0.10 1814.02 42.63 0.70 1859.19 42.64 0.22 1902.28 42.64 0.50 1946.10 42.62 0.54 1989.69 42.59 0.53 94.4 95.1 91.2 93.7 94.7 91.6 93.7 92.6 92.8 92.7 5109.34 2031.38 1496.43 1373.80 5192.79 2073.96 1528.82 1401.51 5275.36 2115.87 1559.47 1430.09 5358.36 2157.35 1588.99 1459.26 5441.62 2198.09 1618.20 1487.66 2031.41 42.55 0.76 2074.01 42.51 0.63 2115.92 42.52 1.79 2157.39 42.56 0.49 2198.12 42.59 0.66 93.9 5526.37 2238.52 1647.29 1515.76 2238.55 42.62 93.1 5610.97 2277.37 1675.61 1542.36 2277.40 42.63 92.60 5695.98 2314.09 1702.59 1567.25 2314.11 42.63 94.80 5784.21 2348.75 1728.32 1590.50 2348.78 42.62 0.62 1.43 1.68 2.55 Page 2 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azm DLS # Depth angle angle length depth section +N/S- +E/W- displacement (deg/ /ft) /de~) (de~) /ft) lft) Ift) (ft) (ft) (fi:) /de~) lOOf) 70 6409.09 18.85 41.7 93.00 5871.83 2379.90 1751.72 1611.08 2379.94 42.61 1.59 71 6502.72 18.11 41.0 93.60 5960.60 2409.56 1773.98 1630.69 2409.60 42.59 0.83 72 6596.11 15.37 41.6 93.40 6050.03 2436.45 1794.20 1648.43 2436.49 42.58 2.94 73 6689.61 13.90 37.1 93.50 61 40.50 2460.01 1812.43 1663.43 2460.06 42.55 1.99 74 6783.21 13.50 35.6 93.60 6231.44 2482.03 1830.28 1676.57 2482.10 42.49 0.57 75 6878.29 11.48 38.6 95.10 6324.28 2502.48 1846.70 1688.94 2502.56 42.45 2.23 76 6967.36 9.75 44.0 89.1 6411.86 2518.87 1859.06 1699.72 2518.95 42.44 2.24 77 7065.11 9.81 43.0 97.7 6508.14 2535.47 1871.1 0 1711.1 4 2535.55 42.44 0.18 78 7165.65 9.96 42.1 100.5 6607.14 2552.72 1883.81 1722.80 2552.80 42.44 0.21 79 7258.62 9.75 41.7 93.0 6698.77 2568.63 1895.65 1733.44 2568.71 42.44 0.24 80 7352.6 9.42 42.8 94.0 6791.46 2584.28 1907.24 1743.96 2584.37 42.44 0.40 81 7445.71 8.83 42.6 93.1 6883.38 2599.05 1918.09 1753.97 2599.13 42.44 0.63 82 7505.05 8.74 41.6 59.3 6941.98 2608.10 1924.81 1760.04 2608.19 42.44 0.30 Projected 7583.00 8.74 41.6 78.0 7019.08 2619.95 1933.67 1767.91 2620.04 42.44 0.00 Page 3 OONFIDENTIAL RECEIVED APR 2 7 1998 BPXA PDC B.P. EXPLORATION NWE FIELD, WELL NO. 1-02 " PRUDHOE BAY, W.O.A., ALASKA Gyro Continuous Multishot Survey Inside 3.5" TUBING Survey date: 03-APRIL, 1998 Job number :A0498GCE448 CONTENTS JOB NUMBER :A0498GCE448 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING g QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' A0498GCE448 Tool 758 was run in WELL# 1-02 on SCHLUMBERGER 7/32" wireline inside 3.5"TUBING. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER: A0498GCE448 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth 'by Gyrodata Limited. This report represents a 'directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A0498GCE448 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: NWE FIELD, ALASKA WELL: 1-02 LATITUDE: 70.34 N LONGITUDE: 148.7 W SURVEY DATE: 03 -APRIL, 1998 SURVEY TYPE : GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 77.2' MAX. SURVEY DEPTH: 7450' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-7450' APl NUMBER: 050-029-22865 TARGET DIRECTION: 42.9 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, W.O.A. , ALASKA Job Number: 448RPT Run Date: 3-Apr-98 10:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350000 deg. N Sub-sea Correction from Vertical Reference: 77.2 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 42.900 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i re c t i on a i Survey B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, Job Number: 448RPT W.O.A., ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet 0.0 0.00 0.00 0.0 100.0 .35 47.54 100.0 200.0 .18 80.93 200.0 300.0 .49 67.67 300.0 400.0 1.00 50.95 400.0 VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. 501.0 1.99 36.06 501.0 600.0 3.04 36.75 599.9 700.0 4.94 37.12 699.6 800.0 8.16 40.38 798.9 900.0 10.65 42.30 897.6 HORIZONTAL COORDINATES feet 1000.0 13.43 42.17 995.4 1101.0 15.77 42.05 1093.1 1150.0 17.26 41.93 1140.1 1200.0 18.12 41.90 1187.7 1250.0 18.39 41.93 1235.2 0.0 0 00 0.0 0.0 0.00 N 0.00 E .3 .35 .3 47.5 .21 N .23 E .7 .23 .8 54.0 .44 N .61 E 1.2 .32 1.3 61.5 .63 N 1.16 E 2.5 .55 2.6 59.0 1.34 N 2.23 E 1300.0 18.68 41.94 1282.6 1350.0 19.20 42.30 1329.9 1400.0 20.16 42.03 1377.0 1450.0 21.01 41.29 1423.8 1500.0 21.93 39.99 1470.3 5.1 9.4 16.3 27.7 44.1 1550.0 22.19 39.82 1516.7 1600.0 21.91 39.46 1563.0 1650.0 22.12 39.41 1609.4 1700.0 22.33 39.45 1655.6 1750.0 22.48 39.78 1701.9 64.9 90.4 104.3 119.5 135.1 151.0 167.3 184.1 201.7 220.0 1.05 5.2 50.0 1.05 9.4 43.8 1.90 16.4 40.9 3.24 27.8 40.2 2.51 44.1 40.7 2.78 64.9 41.2 2.31 90.4 41.4 3.06 104.3 41.5 1.72 119.5 41.6 .54 135.2 41.6 .58 151.1 41.6 1.07 167.3 41.7 1.93 184.1 41.7 1.77 201.7 41.7 2.07 220.0 41.6 .53 238.8 41.5 .61 257.6 41.4 .42 276.3 41.2 .42 295.2 41.1 .40 314.2 41.0 238.7 257.5 276.2 295.0 314.1 3.31 N 3.95 E 6.81 N 6.53 E 12.36 N 10.71 E 21.20 N 17.91 E 33.45 N 28.73 E 48.89 N 42.75 E 67.78 N 59.82 E 78.13 N 69.14 E 89.44 N 79.29 E 101.09 N 89.75 E 112.92 N 100.37 E 124.95 N 111.26 E 137.44 N 122.56 E 150.57 N 134.24 E 164.46 N 146.16 E 178.87 N 158.20 E 193.32 N 170.18 E 207.79 N 182.08 E 222.40 N 194.09 E 237.08 N 206.25 E Page A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, Job Number: 448RPT W.O.A., ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 1800.0 22.47 40.38 1748.1 1850.0 22.48 40.72 1794.3 1900.0 21.97 41.10 1840.6 1950.0 21.97 41.15 1886.9 2000.0 22.20 41.14 1933.3 2050.0 22.26 41.16 1979.5 2100.0 22.02 41.23 2025.9 2150.0 22.29 41.21 2072.2 2200.0 22.82 41.26 2118.3 2250.0 23.35 41.46 2164.3 2300.0 23.85 41.48 2210.2 2350.0 24.18 41.48 2255.8 2400.0 24.88 41.10 2301.3 2450.0 25.44 41.01 2346.6 2500.0 25.83 41.04 2391.7 2550.0 26.90 41.95 2436.5 2600.0 27.53 42.02 2480.9 2650.0 27.92 42.00 2525.2 2700.0 27.80 42.13 2569.4 2750.0 27.51 41.97 2613.7 2800.0 27.46 41.81 2658.0 2850.0 27.67 41.67 2702.4 2900.0 27.96 41.58 2746.6 2950.0 27.90 41.30 2790.8 3000.0 27.83 41.14 2835.0 333.2 f46 333.3 41.0 352.3 .26 352.5 40.9 371.2 1.05 371.4 40.9 389.9 .04 390.1 41.0 408.6 .46 408.9 41.0 427.5 446.4 465.2 484.4 504.0 524.0 544.3 565.1 586.3 608.0 .12 427.8 41.0 .49 446.6 41.0 .55 465.5 41.0 1.07 484.7 41.0 1.06 504.3 41.0 1.01 524.3 41.0 .65 544.6 41.0 1.44 565.4 41.1 1.13 586.6 41.1 .77 608.3 41.1 630.2 2.29 630.5 41.1 653.0 1.26 653.3 41.1 676.3 .78 676.6 41.1 699.6 .28 700.0 41.2 722.8 .60 723.2 41.2 745.9 769.0 792.4 815.8 839.1 .17 746.2 41.2 .44 769.4 41.2 .60 792'.7 41.2 .29 816.1 41.2 .20 839.5 41.2 HORIZONTAL COORDINATES feet 251.71 N 218.55 E 266.23 N 230.98 E 280.52 N 243.36 E 294.61 N 255.67 E 308.77 N 268.03 E 323.01 N 280.48 E 337.18 N 292.89 E 351.37 N 305.31 E 365.79 N 317.96 E 380.50 N 330.91 E 395.50 N 344.17 E 410.74 N 357.65 E 426.34 N 371.34 E 442.37 N 385.31 E 458.69 N 399.51 E 475.32 N 414.22 E 492.32 N 429.52 E 509.60 N 445.09 E 526.95 N 460.74 E 544.18 N 476.28 E 561.35 N 491.69 E 578.62 N 507.09 E 596.06 N 522.59 E 613.61 N 538.09 E 631.19 N 553.49 E Page A Gyr oda t a D i re c t i ona i Survey B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, Job Number: 448RPT W.O.A., ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3050.0 27.83 40.84 2879.2 3100.0 27.91 40.77 2923.4 3150.0 27.61 40.66 2967.6 3200.0 27.68 40.50 3011.9 3250.0 27.60 40.34 3056.2 862.5 ~28 862.8 41.2 885.8 .17 886.2 41.2 909.1 .62 909.5 41.2 932.3 .20 932.7 41.2 955.5 .21 955.9 41.2 648.81 N 568.80 E 666.51 N 584.07 E 684.16 N 599.27 E 701.78 N 614.36 E 719.44 N 629.40 E 3300~0 27.86 39.84 3100.5 3350.0 28.25 39.42 3144.6 3400.0 28.59 39.25 3188.6 3450.0 28.40 38.80 3232.5 3500.0 28.27 38.37 3276.5 978.7 .69 979.2 41.2 1002.2 .88 1002.7 41.1 1025.9 .69 1026.5 41.1 1049.7 .57 1050.3 41.0 1073.4 .49 1074.0 41.0 737.24 N 644.38 E 755.35 N 659.38 E 773.76 N 674.47 E 792.29 N 689.49 E 810.84 N 704.29 E 3550.0 28.19 38.18 3320.6 3600.0 28.29 38.11 3364.6 3650.0 27.57 42.07 3408.8 3700.0 27.11 44.19 3453.2 3750.0 27.11 44.22 3497.7 1097.0 .24 1097.6 40.9 1120.5 .21 1121.3 40.9 1143.9 3.99 1144.7 40.8 1166.9 2.15 1167.6 40.9 1189.7 .03 1190.4 41.0 829.40 N 718.94 E 848.01 N 733.55 E 865.92 N 748.62 E 882.68 N 764.31 E 899.01 N 780.20 E 3800.0 26.66 44.06 3542.3 3850.0 26.32 43.79 3587.1 3900.0 26.14 43.65 3631.9 3950.0 26.46 45.38 3676.7 4000.0 26.89 46.56 3721.4 1212.3 .91 1212.9 41.0 1234 . 6 . 74 1235 . 2 41 . 1 1256.7 .36 1257.3 41.1 1278.8 1.65 1279.4 41.2 1301.2 1.38 1301.8 41.3 915.24 N 795.95 E 931.31 N 811.42 E 947.28 N 826.69 E 963.07 N 842.22 E 978.67 N 858.36 E 4050.0 26.92 46.56 3766.0 4100.0 26.81 46.49 3810.6 4150.0 27.03 46.43 38'55.2 4200.0 26.95 46.27 3899.7 4250.0 27.13 46.27 3944.3 1323 . 8 . 06 1324 . 3 41 . 3 1346.3 .24 1346.8 41.4 1368.9 .46 1369.3 41.5 1391.6 . 23 1392 . 0 41.6 1414 . 3 . 37 1414 . 6 41 . 7 994.23 N 874.79 E 1009.77 N 891.18 E 1025.37 N 907.59 E 1041.03 N 924.01 E 1056.74 N 940.44 E A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, Job Number: 448RPT W.O.A., ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 4300.0 26.99 46.69 3988.8 4350.0 27.06 46.22 4033.3 4400.0 27.61 46.09 4077.8 4450.0 27.88 46.14 4122.0 4500.0 28.23 46.05 4166.1 4550.0 28.28 46.05 4210.2 4600.0 28.28 45.70 4254.2 4650.0 28.43 45.52 4298.2 4700.0 28.28 45.53 4342.2 4750.0 28.44 45.27 4386.2 4800.0 28.46 45.25 4430.2 4850.0 28.32 45.27 4474.2 4900.0 28.64 45.00 4518.1 4950.0 28.56 44.82 4562.0 5000.0 28.59 44.61 4605.9 5050.0 28.69 44.12 4649.8 5100.0 28.26 43.84 4693.8 5150.0 28.24 43.62 4737.8 5200.0 28.40 43.50 4781.8 5250.0 28.21 43.27 4825.8 5300.0 28.17 42.84 4869.9 5350.0 27.80 42.47 4914.1 5400.0 27.62 42.24 4958.3 5450.0 27.29 41.85 5002.7 5500.0 27.08 41.44 5047.2 1437.0 1459.7 1482.6 1505.8 1529.3 1552.9 1576.6 1600.3 1624.0 1647.7 1671.5 1695.3 1719.1 1743.0 1766.9 1790.9 1814.7 1838.4 1862.1 1885.8 1909.4 1932.9 1956.2 1979.2 2002.0 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. '.~48 1437.3 41.7 · 46 1459 . 9 41.8 1 . 11 1482 . 8 41 . 9 · 54 1506 . 0 41.9 .70 1529.5 42.0 .11 1553.1 42.1 .33 1576.7 42.1 .34 1600.4 42.2 .30 1624.1 42.2 .41 1647.8 42.3 .04 1671.6 42.3 .28 1695.4 42.4 .68 1719.2 42.4 .24 1743.1 42.4 .21 1767.0 42.5 .51 1790.9 42.5 .90 1814.8 42.5 .21 1838.4 42.5 .34 1862.2 42.5 .44 1885.9 42.5 .41 1909.5 42.6 .83 1932.9 42.6 .42 1956.2 42.6 .76 1979.2 42.5 .56 2002.1 42.5 HORIZONTAL COORDINATES feet 1072.40 N 956.93 E 1088.05 N 973.40 E 1103.96 N 989.95 E 1120.09 N 1006.73 E 1136.40 N 1023.67 E 1152.82 N 1040.71 E 1169.32 N 1057.71 E 1185.93 N 1074.68 E 1202.56 N 1091.62 E 1219.24 N 1108.53 E 1236.01 N 1252.74 N 1269.56 N 1286.51 N 1303.50 N 1320.64 N 1337.79 N 1354.89 N 1372.08 N 1389.31 N 1406.57 N 1423.83 N 1441.01 N 1458.13 N 1475.19 N 1125.45 E 1142.34 E 1159.24 E 1176.13 E 1192.96 E 1209.72 E 1226.27 E 1242.63 E 1258.98 E 1275.26 E 1291.39 E 1307.29 E 1322.95 E 1338.39 E 1353.57 E Page A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, Job Number: 448RPT W.O.A. , ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 5550.0 27.18 41.09 5091.7 5600.0 26.91 40.62 5136.2 5650.0 27.02 41.53 5180.8 5700.0 27.13 44.85 5225.3 5750.0 26.78 45.00 5269.9 5800.0 26.63 44.66 5314.5 5850.0 26.28 44.67 5359.3 5900.0 25.98 44.60 5404.2 5950.0 25.84 44.75 5449.2 6000.0 25.42 44.69 5494.2 6050.0 25.07 44.41 5539.5 6100.0 24.61 44.23 5584.8 6150.0 23.62 43.95 5630.5 6200.0 23.11 43.44 5676.4 6250.0 22.06 43.24 5722.5 6300.0 20.68 43.61 5769.1 6350.0 19.74 43.35 5816.0 6400.0 18.74 42.88 5863.2 6450.0 18.52 42.43 5910.6 6500.0 18.18 41.82 5958.1 6550.0 17.44 41.34 6005.7 6600.0 15.22 40.49 6053.7 6650.0 14.25 39.12 6102.0 6700.0 13.94 37.74 6150.5 6750.0 13.65 35.88 6199.1 2024.8 2047.6 2070.2 2093.0 2115.6 2138.1 2160.3 2182.3 2204.2 2225.8 2247.1 2268.1 2288.5 2308.4 2327.6 2345.8 2363.1 2379.5 2395.5 2411.2 2426.5 2440.6 2453.3 2465.4 2477.3 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. '338 2024.9 42.5 .68 2047.6 42.5 .85 2070.3 42.5 3.03 2093.0 42.5 .71 2115.7 42.5 .43 2138.1 42.5 .69 2160.4 42.6 .61 2182.4 42.6 .29 2204.2 42.6 .86 2225.8 42.6 .73 2247.1 42.6 .95 2268.1 42.7 1.99 2288.6 42.7 1.09 2308.4 42.7 2.09 2327.6 42.7 2.79 2345.8 42.7 1.89 2363.1 42.7 2.02 2379.5 42.7 .53 2395.5 42.7 .77 2411.3 42.7 1.51 2426.5 42.7 4.46 2440.6 42.7 2.06 2453.3 42.7 .91 2465.4 42.6 1.07 2477.3 42.6 HORIZONTAL COORDINATES feet 1492.33 N 1368.61 E 1509.53 N 1383.48 E 1526.62 N 1398.38 E 1543.20 N 1413.95 E 1559.25 N 1429.95 E 1575.18 N 1591.03 N 1606.69 N 1622.23 N 1637.60 N 1652.80 N 1667.82 N 1682.49 N 1696.83 N 1710.79 N 1724.03 N 1736.56 N 1748.58 N 1760.33 N 1772.00 N 1783.44 N 1794.06 N 1803.82 N 1813.36 N 1822.90 N 1445.79 E 1461.45 E 1476.92 E 1492.29 E 1507.50 E 1522.47 E 1537.14 E 1551.35 E 1565.05 E 1578.23 E 1590.76 E 1602.64 E 1613.90 E 1624.72 E 1635.28 E 1645.43 E 1654.64 E 1662.79 E 1670.36 E 1677.50 E Page A Gyroda t a D i re c t i ona i Survey B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, Job Number: 448RPT W.O.A., ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 6800.0 13.58 35.29 6247.7 6850.0 12.32 36.93 6296.4 6900.0 11.18 39.28 6345.3 6950.0 10.26 42.40 6394.5 7000.0 9.49 45.11 6443.7 7050.0 9.68 44.70 6493.0 7100.0 9.76 43.78 6542.3 7150.0 9.87 43.28 6591.6 7200.0 9.75 43.07 6640.8 7250.0 9.68 43.02 6690.1 7300.0 9.48 43.26 6739.4 7350.0 9.33 43.72 6788.8 7400.0 9.04 43.63 6838.1 7450.0 8.72 43.63 6887.5 Final Station Closure: Distance: 2488.9 2500.1 2510.2 2519.5 2528.1 2536.4 2544.8 2553.3 2561.9 2570.3 2578.6 2586.8 2594.8 2602.5 2602.54 J31 2489.0 42.6 2.62 2500.1 42.6 2.48 2510.3 42.5 2.17 2519.5 42.5 1.80 2528.1 42.5 42 2536.4 42.5 34 2544.9 42.6 28 2553.4 42.6 25 2561.9 42.6 13 2570.3 42.6 41 2578.7 42.6 34 2586.8 42.6 59 2594.8 42.6 63 2602.5 42.6 ft Az: 42.57 HORIZONTAL COORDINATES feet 1832.47 N 1841.53 N 1849.54 N 1856.58 N 1862.78 N 1868.68 N 1874.73 N 1880.91 N 1887.12 N 1893.28 N 1899.36 N 1905.29 N 1911.06 N 1916.64 N 1684.35 E 1690.95 E 1697.22 E 1703.29 E 1709.21 E 1715.09 E 1720.98 E 1726.85 E 1732.68 E 1738.44 E 1744.13 E 1749.75 E 1755.26 E 1760.59 E deg. page A Gyroda t a Di re c t ional Survey for B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, W.O.A., ALASKA Job Number: SUB448 Run Date: 3-Apr-98 10:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350000 deg. N Sub-sea Correction from Vertical Reference: 77.2 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 42.900 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i re c t iona i Survey B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, Job Number: SU3448 W.O.A., ALASKA SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet -77.2 0.00 0.00 0.0 100.0 .22 73.32 177.2 200.0 .42 70.70 277.2 300.0 .88 54.76 377.2 400.0 1.76 39.56 477.2 500.0 2.80 36.59 577.2 600.0 4.51 37.04 677.2 700.0 7.45 39.67 777.2 800.0 10.14 41.90 877.2 900.0 12.92 42.20 977.2 1000.0 15.39 42.07 1077.2 1100.0 17.93 41.91 1177.2 1200.0 18.65 41.94 1277.2 1300.0 20.17 42.02 1377.2 1400.0 21.96 39.96 1477.2 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 .0 21.97 39.45 1577.2 .0 22.40 39.60 1677.2 .0 22.47 40.60 1777.2 .0 21.97 41.14 1877.2 .0 22.25 41.16 1977.2 .0 22.35 41.21 2077.2 .0 23.49 41.47 2177.2 .0 24.51 41.31 2277.2 .0 25.71 41.03 2377.2 .0 27.48 42.02 2477.2 VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 0.0 0'[00 0.0 0.0 .6 .26 .8 52.6 1.1 .30 1.3 59.8 2.2 .50 2.6 59.6 4.5 .93 5.2 52.1 8.4 1.05 9.4 45.2 14 . 8 1.71 16 . 4 41 . 6 25.2 2.95 27.8 40.3 40.7 2.66 44.1 40.6 61 . 0 2 . 73 64 . 9 41 . 1 86.2 2.39 90.4 41.4 116.1 2.01 119.5 41.5 149.2 .58 151.1 41.6 184.2 1.93 201.7 41.7 222.8 1.84 238.8 41.6 263.2 .55 276.3 41.3 303.9 .41 314.2 41.1 345.2 .34 352.5 41.0 385.9 .25 390.1 40.9 426.6 .14 427.8 41.0 467.3 .61 484.7 41.0 509.6 1.04 524.3 41.0 554.1 1.03 565.4 41.1 601.0 .89 608.3 41.1 651.1 1.35 653.3 41.1 Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E .39 N .52 E .59 N 1.03 E 1.18 N 1.99 E 2.85 N 3.54 E 6.01 N 5.94 E 11.11 N 9.77 E 19.27 N 16.33 E 30.91 N 26.49 E 46.02 N 40.14 E 64.70 N 57.04 E 86.94 N 77.04 E 111.57 N 99.16 E 137.50 N 122.62 E 166.60 N 147.94 E 197.75 N 173.82 E 229.24 N 199.76 E 260.86 N 226.39 E 291.65 N 253.08 E 322.29 N 279.85 E 352.94 N 306.69 E 384.71 N 334.63 E 418.07 N 364.08 E 453.46 N 394.95 E 490.90 N 428.24 E A Gyrodat a Di re c t i ona i Survey B.P. EXPLORATION NWE WELL NO. 1-02 PRUDHOE BAY FIELD, Job Number: SUB448 W.O.A., ALASKA SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 2500.0 27.75 42.10 2577.2 2600.0 27.55 41.75 2677.2 2700.0 27.92 41.38 2777.2 2800.0 27.83 40.85 2877.2 2900.0 27.63 40.63 2977.2 3000.0 27.72 40.11 3077.2 3100.0 28.50 39.29 3177.2 3200.0 28.27 38.36 3277.2 3300.0 28.08 39.24 3377.2 3400.0 27.11 44.21 3477.2 703.7 '[34 723.2 41.2 755.9 .29 769.4 41.2 808.6 .39 816.1 41.2 861.4 .28 862.8 41.2 914.1 .53 932.7 41.2 966.5 .44 979.2 41.2 1019.8 .74 1026.5 41.1 1073.8 .49 1097.6 41.0 1127.2 1.29 1144.7 40.9 1179.2 1.01 1190.4 40.9 3500.0 26.39 43.85 3577.2 3600.0 26.46 45.39 3677.2 3700.0 26.89 46J55 3777.2 3800.0 26.99 46.35 3877.2 3900.0 27.02 46.58 3977.2 1229.7 .77 1235.2 41.1 1279.0 1.65 1301.8 41.2 1329.5 .10 1346.8 41.4 1380.1 .35 1392.0 41.6 1431.1 .45 1437.3 41.7 4000.0 27.60 46.10 4077.2 4100.0 28.24 46.05 4177.2 4200.0 28.36 45.60 4277.2 4300.0 28.41 45.33 4377.2 4400.0 28.34 45.25 4477.2 1482.3 1.10 1482.8 41.9 1535.2 .55 1553.1 42.0 1589.0 .34 1600.4 42.2 1642.9 .39 1647.8 42.3 1696.9 .31 1719.2 42.4 4500.0 28.57 44.75 4577.2 4600.0 28.42 43.95 4677.2 4700.0 28.38 43.51 4777.2 4800.0 28.11 42.78 4877.2 4900.0 27.48 42.07 4977.2 1751.3 .23 1767.0 42.4 1805.8 .75 1814.8 42.5 1859.6 .32 1862.2 42.5 1913.3 .48 1932.9 42.6 1966.0 .56 1979.2 42.6 Page HORIZONTAL COORDINATES feet 529.99 N 463.48 E 568.82 N 498.35 E 608.23 N 533.33 E 648.03 N 568.11 E 687.97 N 602.53 E 727.88 N 636.51 E 769.00 N 670.57 E 811.13 N 704.52 E 853.11 N 737.84 E 891.49 N 772.87 E 927.77 N 808.01 E 963.23 N 842.39 E 998.13 N 878.91 E 1033.11 N 915.71 E 1068.32 N 952.63 E 1103.75 N 1140.52 N 1177.99 N 1215.82 N 1253.90 N 1292.38 N 1331.33 N 1370.28 N 1409.42 N 1448.29 N 989.74 E 1027.94 E 1066.57 E 1105.07 E 1143.50 E 1181.95 E 1220.04 E 1257.26 E 1294.01 E 1329.52 E FUNCTION TEST JOB NUMBER' A0498GCE448 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. .INCLINATION M.D. ft 1 2 3 4 5 1101 15.77 15.77 15.77 15.77 15.7'/ M.D. ft 1 2 3 4 5 1101 42.05 42.08 42.05 42.19 42.12 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: A0498GCE448 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 758 GYRO SECTION DATA SECTION POWER SECTION TOOL No. 718 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0147 POWER SUPPLY C0111 PRINTER C0112 INTERFACE COMPUTER A0054 POWER SUPPLY C0089 PRINTER C0086 INTERFACE A0433 A0085 A0079 A0143 A0349 A0107 A0029 A0055 WIRELINE COMPANY: CABLE SIZE: 7/32" SCHLUMBERGER RUNNING GEAR 2.25" HOUSING W/CENTRALIZERS AND ECCENTRIC BAR TOTAL LENGTH OF TOOL: 25' MAXIMUM O.D.: 2.25 INCHES TOTAL WEIGHT OF TOOL: 250 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: A0495GCE448 THURSDAY 4/03/98 08:00 10:00 10:15 10:30 11:45 13:00 13:45 15:15 18:00 19:00 ALERTED. LOAD EQUIPMENT ARRIVE NWE MU TOOL. PICK UP GYRO, WARM UP TOOL SURVEY TO 7450'. SURVEY OUT CONTINUOUS. LD TOOL. BD TOOL. RETURN TO ATLAS. CHECK TOOL, PROCESS RESULTS. PRINT OUT RESULTS, TAKE TO BOC FRIDAY, 04/04/98 09:00 CHECK ON JOB ON POOL 7 BP EXPLOR_~TiO.N] DATE OF SURVEY- 031198 · PBU / NWE !-02 500292286500 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/19/98 PAGE 1 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AKEI80!59 KELLY BUSHING ELEV. = 77.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -77.20 0 0 N .00 E .00 207.00 207.00 129.80 0 7 N 21.78 W .06 298.40 298.40 221.20 0 24 N 74.59 E .48 390.60 390.59 313.39 0 51 N 53.29 E .54 482.10 482.08 404.88 1 17 N 38.49 E .55 .00N .00E .00 .21N .08W .10 .39N .19E .42 .89N 1.06E 1.38 2.10N 2.25E 3.08 572.70 572.62 495.42 2 22 N 31.87 E 1.23 666.26 666.03 588.83 4 2 N 34.69 E 1.78 760.20 759.55 682.35 6 30 N 37.29 E 2.64 851.70 850.16 772.96 9 25 N 40.11 E 3.21 943.30 940.23 863.03 11 26 N 41.82 E 2.24 4.50N 3.88E 5.94 8.86N 6.78E 11.11 15.82N 11.89E 19.68 25.67N 19.86E 32.32 38.18N 30.75E 48.90 1034.80 1029.43 952.23 14 15 N 41.86 E 3.07 1128.10 1119.38 1042.18 16 28 N 42.75 E 2.39 1221.20 1208.15 1130.95 18 33 N 42.35 E 2.26 1314.30 1296.31 1219.11 18 54 N 42.96 E .42 1406.30 1382.95 1305.75 20 22 N 41.65 E 1.67 53.34N 44.32E 69.24 71.60N 60.96E 93.95 92.25N 79.90E 121.97 114.24N 100.16E 151.87 137.11N 120.96E 182.78 1501.02 1471.25 1394.05 22 1 N 40.71 E 1.78 1595.60 1559.09 1481.89 21 30 N 39.00 E .86 1688.90 1645.62 1568.42 22 23 N 40.39 E 1.09 1782.20 1731.80 1654.60 22 41 N 40.84 E .37 1873.90 1816.45 1739.25 22 32 N 42.14 E .57 162.90N 143.51E 217.02 189.82N 165.99E 252.04 216.64N 188.27E 286.86 243.79N 211.54E 322.59 270.20N 234.90E 357.84 1965.35 1901.10 1823.90 21 54 N 41.91 E .71 2056.70 1985.69 1908.49 22 28 N 40.73 E .79 2150.00 2072.00 1994.80 22 9 N 42.42 E .77 2156.00 2077.55 2000.35 22 25 N 41.96 E 5.37 2243.20 2157.87 2080.67 23 22 N 42.26 E 1.10 2335.60 2242.34 2165.14 24 26 N 41.12 E 1.25 2427.90 2326.04 2248.84 25 25 N 42.07 E 1.16 2523.30 2411.93 2334.73 26 10 N 42.64 E .83 2615.90 2494.38 2417.18 27 56 N 43.24 E 1.93 2707.40 2575.20 2498.00 27 58 N 42.40 E .43 295.89N 258 . 06E 392.42 321.80N 280.83E 426.90 348.30N 304.34E 462.31 349.99N 305.86E 464.59 375.16N 328.62E 498.52 403.13N 353.51E 535.95 432.22N 379.34E 574.84 462.90N 407.32E 616.36 493.73N 436.02E 658.49 525.19N 465.18E 701.38 2712.30 2579.53 2502.33 27 55 N 41.96 E 4.31 2728.40 2593.74 2516.54 28 8 N 43.29 E 4.11 526.90N 466.72E 703.68 532.46N 471.84E 711.24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 711.44 FEET AT NORTH 41 DEG. 32 MIN. EAST AT MD = 2728 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 42.90 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 2,728.40' MD RECEIVED NAR 2 1998 BPXA PDC SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EX PLOR_AT I ON PBU / NWE 1-02 500292286500 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/19/98 DATE OF SURVEY: 031198 JOB NUMBER: AKEI80159 KELLY BUSHING ELEV. = 77.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -77.20 1000.00 995.62 918.42 2000.00 1933.25 1856.05 2728.40 2593.74 2516.54 .00 N .00 E .00 47.19 N 38.81 E 4.38 4.38 305.51 N 266.69 E 66.75 62.37 532.46 N 471.84 E 134.66 67.91 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ENTIAL PAGE 8P E}~PLO~TION PBU / N~{E ' 02 500292286500 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/19/98 DATE OF SURVEY: 031198 JOB NUMBER: AKEI80t59 KELLY BUSHING ELEV. = 77.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -77.20 .00 N .00 E 77.20 77.20 .00 .00 N .00 E 177.20 177.20 100.00 .15 N .06 W 277.20 277.20 200.00 .35 N .05 E 377.21 377.20 300.00 .77 N .90 E .0 .0 .0 .0 .0 0 0 .00 0 .00 0 .00 t .01 477.22 477.20 400.00 2.02 N 2.18 E .0 577.28 577.20 500.00 4.66 N 3.98 E .0 677.46 677.20 600.00 9.51 N 7.23 E .2 777.98 777.20 700.00 17.49 N 13.18 E .7 879.11 877.20 800.00 29.10 N 22.75 E 1.9 2 .02 8 .06 6 .18 8 .52 1 1.14 981.10 977.20 900.00 44.05 N 36.00 E 3. 1084.13 1077.20 1000.00 62.48 N 52.53 E 6. 1188.55 1177.20 1100.00 84.56 N 72.90 E 11. 1294.10 1277.20 1200.00 109.45 N 95.70 E 16. 1400.16 1377.20 1300.00 135.51 N 119.54 E 22. 90 1.99 93 3.03 35 4.42 90 5.54 96 6.07 1507.43 1477.20 1400.00 164.72 N 145.08 E 30. 1615.07 1577.20 1500.00 195.36 N 170.48 E 37. 1723.05 1677.20 1600.00 226.55 N 196.70 E 45. 1831.40 1777.20 1700.00 258.09 N 223.99 E 54. 1939.59 1877.20 1800.00 288.74 N 251.64 E 62. 23 7.27 87 7.63 85 7.99 20 8.35 39 8.19 2047.52 1977.20 1900.00 319.14 N 278.54 E 70. 2155.63 2077.20 2000.00 349.90 N 305.77 E 78. 2264.25 2177.20 2100.00 381.34 N 334.23 E 87. 2373.89 2277.20 2200.00 415.06 N 363.93 E 96. 2484.60 2377.20 2300.00 450.34 N 395.75 E 107. 32 7.93 43 8.11 05 8.63 69 9.63 40 10.72 2596.45 2477.20 2400.00 487.09 N 429.78 E 119. 2709.66 2577.20 2500.00 525.99 N 465.88 E 132. 2728.40 2593.74 2516.54 532.46 N 471.84 E 134. 25 11.85 46 13.21 66 2.20 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Son ic Evaluation using the D~oole Sonic Tool (DSO Dates Logged: 2~ Mar 98 Depths Analyzed: Data Used: 2800 - 7550 (md) DSI Sonic PREPARED BY: NElL C. HEWITT, Schlumberger GeoQuest West and South Africa April 4~, 1997 ~R-U/Y DTM-B SURFACE EQUIPMENT DOWNHOLE EQUIPMENT Date Logged: 21-MAR-98 Depths Analyzed: 2800 - 7550 ft (md) Data Used: DSI Sonic Upper Dipole Lower Dipole and P & S and First motion modes LEH-Q LEH-Q DTC-H EOM-KC DTCH0-A DTA-A EOH-KE DTA-A SG-I'-L SGH-K SGC-SA SGD-TAA DSST-B SPAC-AA EOH-SC SMDR-.&& @SIJ-BA SMDX-AA AH-X~ GPIT-A/B GPIC-AC GPIH-^ CTEM TolS'tatu~ ToolSt~t~ Gamma Ray I--~ __ 88.8 __66.5 __ 61,6 I:WF __ 6.0 HVDF ~ Ton~ion Gl)IT 0.0 TOOL ZERO MAXIMUM STRING DIAMETER ;3.~ IN MEASUREMENTS RELATIVE TO TOOL ZERO ALL LENGTHE; IN FEET 71.7 69.5 66.5 62.5 57.0 6.0 4.0 Purpose of Reprocessing: Reprocessing of the three modes of the DSI tool were made across the logged t determine: Compressional Slowness Shear Slowness. Vp/Vs and Poissons Ratio. Enclosures: This Discussion references only MEASURED DEPTH. Included in this report are:. · 1/500 scale Profiles derived from the various modes. Introduction The NEW 1-02 wellbore traverses a series of shale and sand bodies over the interval. 9 5/8" casing was set at 2827 ft after drilling to that depth. 8 ½" bit was used to drill to TD 7582 ft. The DSI mn was made over this openhole section. In the shallow portions of this well, the shear slowness is often similar to the mud wave slowness. Shear slowness from the Dipole mode is tmaffected while the P&S mode is unable to resolve the Shear from the mudwave. The P&S mode can resolve only the P wave in this well. The eight waveforms are reprocessed for each of the 3 modes and a set of Slowness (Dt) curves are computed. The processing sequence for each mode is . 2. 3. 4. 5. 6. Filter waveforms Slowness Time Coherence Peak Energy Labeling iLabel Edit Borehole Compensation Post Processing The first 3 steps are now done in the MAXIS field unit. Peak Energy waveforms ar processed in the GEOFRAME software to correctly label the waveforms. 1. Filterin~ The raw waveform data is treated in the field to remove noise for each of the logging intervals. This was not re-filtered in the computing center 1. DIPOLE Waveforms'l - 2 kHz WINFIR low frequency bandpass filter 2. P&S waveforms: 5 - 15 kHz BUTTERWORTH bandpass filter Example: DIPOLE MODE 1st waveform, before and afterfiltering 2. Slowness- Time Coherence S~ Formation-- Mc~o pole Slowness Time Coherence is applied to the waveform data from the 8 receiver array for each mode. The receivers are spaced 6" apart on the tool so the sonic energy arrives slightly later at each sequential receiver. The set of waveforms are sequentially time shifted and stacked. Slowness (At) vs Time for a single depth - showing the Energy of Stacked waveform Maximum Energy indicated by Blue Arrow BO¸ Slowness (At) Tim e (T) The resulting energy spectrum is relabeled and manually edited to generate a pair of slowness curves for each mode: · DT Compressional Monopole P&S Receiver Array/Transmitter Array · Dt Shear DIPOLE Receiver Array / Transmitter Array · DT Shear Monopole P&S Receiver Array/Transmitter Array (DT Compressional 'First motion Detection' is not based on STC) Slowness- Time Projection vs. Depth (Run 2 - P&S - Receiver Array) GR [A4542501 0 150 Input Shear S lowness 75 775 (us/ft) I · 500I 9/TProiection I r"':'~; ':' ¢1" I Filtered Waveform 4400 4450 4500 4550 4600 3. Peak Energy Labelling The Peak coherence points (Blue Arrows in the Crossplot) Tadpoles in the STC Result for each 6" depth increment are shown as Database Display area 775 (usm) 75 DT2R.PTE .UDP 200.SWP .STC .R 775 75! (us/rt) l l: 100 DT2R .ITP .UDP .200 .SWP .STC.R (ft) 775 /us/ft? 75 Select, :, :','::l ': :::' :"l~ele~,,',' :,',: ~!' I': Name 1'!)12 R .ITP .UOP .ZOO .SWP 'Mode Pal:h Edit Oursor Depth CUrsor/:~rnp J :Save ~,' I I EditOn Trace Amp I Edit area DT2R .ITP .UDP .200 .SWP .S TC .R 775 75 (us/f9 DT2R .ITP .UDP .200 .SWP .S TC .R 775 75 lOOO 2000 3000 4000 5000 6000 7000 /: 7700 LlpdateSummary[Disp] ~1 4. RELABEL Process Expanded scale log, shown with Peak Coherence points as Tadpoles, and the computer generated Interpolation line (Left Side -Black Line). The Analyst may choose to override where data is sparse (Right Side - Pink Line). Borehole Compensation The STC Algorithm has 2 methods to derive slowness. The first is Receive/' An'ay, which consists of determining move out, or coherence, of the eight receiver waveforms at a given transmitter position. The other is Transmitter Array. Once the tool has been run, one can determine the eight positions of the transmitter which correspond to the previous receiver positions and rerun the process. The receiver and transmitter modes are affected in opposite directions when the borehole size changes. Hence the average of the two is approximately 'borehole compensated'. For the D1POLE mode, a slight bias is applied to each raw DT. The DSI measures a flexural wave which is dispersive and must be corrected to obtain true formation shear slowness. Relabelled DT curves - Transmitter Mode and Receiver mode averaged to obtain BHC /. 5 --_,~_,.--_: .- 74-50 .... ~_-= ~::, -? --:-,~ _~ ........ 7500 ~ -~--~::~ " :;:;' :z~_ "~':..... ; l~ ...... '2? !..:' i,- ~;; . .. ,' ~ (._--. 7550 ........ :-:::__::"'-' ~ -- ~:- .z..-. _--~- ---. '.'-~ - ,::~-'~-.~, i~ DTCO- Dt'~:;'~n pres~i-~;~al TI5 H ,W01 1:500 240 40 0 5000 'It ( us/it ) ( us ~) DTSM - IDt Shear TICO .VV[31 340 1 40 13 5000 DTSM (backct3) 540 340 YPAfS ................................................................................. 1.5 25 PR .FIN 0 O5 DTSM Upper Dipole .... 340 140 ( us~t ) DTSM ~rcm Lower 3413 140 ( u~t ~ SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS Anchorage, Alaska FINAL ADT WELL SUMMARY REPORT BP EXPLORATION NWE 1-02 Northwest Eileen Prospect North Slope, Alaska Final Report Summary September 1998 PREPARED FOR: BP EXPLORATION PREPARED BY: John Patton Sperry-Sun Drilling Services Logging Systems Anchorage, Alaska TABLE OF CONTENTS Introduction .............................................................................................................................. A Well Diagram ............................................................................................................................ B Well Summary By Intervals ..................................................................................................... C Conclusions ............................................................................................................................. D Graphical Analysis .......................................................................................................... E & F Well History: .............. E 1) Days Drilling 2) Rotating Hours 3) Bit Hours 4) Bit Footage 5) Torque 6) Time Distribution- Hours 7) Time Distribution- Percent Allocation Pore Pressure Evaluation: .............. F 1) Pore Pressure - Mud weight- TVD 2) Condensed Resistivity - TVD 3) Condensed Pressure Parameters 4) "Dc" Exponent- TVD Log Packet ............................................................................................................................... G 1) Engineering Log (250'/inch) 2) Condensed MWD-TVD Log (250'/inch) 3) Data Disks Bit Record ................................................................................................................................ H Drilling Mud Record ................................................................................................................. I Survey Record ........................................................................................................................... J 1) Anadrill Survey Data Show Reports ........................................................................................................................... K 1) Show Log - Mud Log over Zone of Interest 2) Show Reports - Zones of Interests 3) Pixler Paper- Reference Material ADT Morning Reports ............................................................................................................. L INTRODUCTION Drilling operations for Northwest Eileen #1-02 were initiated 03-09-98, by BP Exploration- Shared Services Drilling. The well was drilled by Nabors Alaska Drilling Rig 18-E on an ice pad location that had been constructed earlier in the winter. The ice pad was located in Section 34, Township 12 North, Range 11 East in the west end of the Prudhoe Bay Unit. This well was the second well of three drilled on this pad and was planned as a moderate reach directional hole to penetrate targeted sands found in the Kupamk Formation predicted on this location. Northwest Eileen 1-02 was drilled to a total depth of 7,583' on 3-21-98. The total number of operating days that was required to reach this depth were 13 days including the spud in date. After completing wire line logs to evaluate the 8.5" hole, a 7" liner was nm and cemented in place on 3-25-98 in preparations to flow test the well. A Sperry-Sun Logging Systems LS2000 Unit was in operation fi.om surface to TD providing full mud logging services. The 2000 Unit and crew provided assistance in the drilling of NEW 1-02 by monitoring essential drilling parameters and gas levels. Also provided were a wide range of geologic interpretations and sampling services. Additional services included the integration of real-time Gamma Ray and EWR information fi.om data supplied by a separate MWD company, Anadrill Schlumberger. The following pages of this report are designed to supply concise historical data of the events that occurred on NWE 1-02 along with some analysis and recommendations for specific problems that were experienced during different sections of the hole. This report differs fi.om our normal ADT Summary in that pore pressure evaluations are abbreviated because a Sperry-Sun ADT Engineer was not present on location during the drilling of the well. All of the information compiled in this report was initially acquired and recorded by the LS2000 Unit and personnel at the well site. The sensors incorporated in this unit are independent from the rig sensors and may differ slightly fi.om those reported by the rig contractor. In addition, any evaluations in this report regarding formation evaluations, pore pressure estimates, or other geologic interpretations are made entirely by Sperry-Sun personnel fi.om examination of the data collected by the LS2000 Unit and reference material made available by the Operator at the rig site. ~,~ I B.P. Ex~,orntion ,~ELL DtRGRRM Casing Progran~ Foraations ' ~ 9 S/8" SOR~flCE CS~ fit 2827' ,..7_=.7--- : I. I. ~ ......... ......... I. ,~ ......... . { " NEST SR g S888 ................................... ,. I, ~' . I. ,, 0 I/Z" HOL~ TO TB [ I, 7688 ,,: --= .... =~ WELL SUMMARY BY INTERVALS Interval: 110'-2,842' Days: 3 Average WOB: 25 klb Hole Size: 12.25" Average RPM: 165 No. Bits: 1 Average GPM: 535 gpm Rotating Hours: 17.5 Average SPP: 1750 psi Deviation: 0 - 27.9 deg Average ROP: 165 fl./hr Mud Weight: 9.0-10.2 ppg Mud Type: Spud Mud Nabors Alaska Drilling Rig 18-E was positioned on location prior to the spud in date of 03-09-98. Structural 20' drive pipe had been set to a depth of 110'. After completing the rig up, a surface diverter system was installed and tested. Drilling operations were initiated by drilling out the structural casing with Bit No. 1 that was run into the hole on a directional assembly. The directional part of the well was started at approximately 450' occasionally sliding to build angle and maintain direction. The angle of the hole was steadily built to a maximum for this interval of' 27.9 degrees recorded from a survey taken at 2,619'. Penetration rates for the first bit mn were good while drilling through the Permafi'ost in mostly gravel and sand. Gravel drilled in this formation was not very large in diameter and did not appear to slough excessively. The mud weight was gradually increased beginning at 800' to a weight of 10.2 ppg by 1,400' in anticipation of drilling into hydrates expected in this area. A short trip back to 655' was performed at 1,498' to condition the hole. The maximum gas reading recorded from this trip was 19 units. Our estimate for the base of the base of the Permafrost was logged at approximately 1,750'. Gas hydrates were encountered just below this threshold beginning at 1,800'. High background gas readings averaging 3,500 units were logged while drilling to 2,050' reaching a maximum of 5,730 at 1,950'. High gas readings averaging 1,000 -2,000 units and consistent connection gas readings were logged while drilling the remainder of the 12 ¼" interval to 2,842' making it difficult to estimate any additional hydrate zones strictly fi'om gas readings. A short trip was performed at 2,842' pulling back to 683' to condition the hole. The maximum trip gas recorded circulating after this trip was 4,820 units. Since electric logs were not needed for the 12 ¼" section, 9 5/8" - 40 lb/ft casing was then mn to a shoe depth of 2,827'. The casing was cemented in place using a two stage cement job. This interval of the well is believed to be near normal pressure. High background gas and connection gas readings were logged after penetrating into gas hydrates starting at 1,800'. These gas readings were believed to be associated with melting hydrates rather than free gas bleeding into the well bore. The average mud weight used below the Permafrost was 10.2-10.3 ppg and appeared to provide for an adequate overbalance condition to stabilize the well bore. Interval: 2,842' to 7,583' Days: Hole Size: No. Bits: Rotating Hours: Deviation: Mud Weight: 10 Average WOB: 5-15(PDC)klb 8 1/2" Average RPM: 330 3 Average GPM: 535 g-pm 56.4 Average SPP: 2250 psi 28.7-8.7 deg Average ROP: 84 ft/hr 9.6/11.6 ppg Mud Type: KCL Poly Discussion: The blow out preventer stack was nippled up and tested. The 9 5/8" surface casing was tested to 3,000 psi for 30 minutes prior to drilling out of the casing cement. Bit No. 2, an 8 1/2" PDC type bit, was used to drill out of the 9 5/8" surface casing along with 20 feet of new hole to 2,862' on 3- 13-98. The hole was then circulated in preparation for runn/ng a leak off test. The test that was performed at this depth yielded a fracture pressure equivalent to 14.7 ppg. The 14.7 ppg value that was observed at this casing seat is somewhat higher than expected for this area of the North Slope. After completing the leak off test, the hole was displace with 9.6 ppg - KCL poly mud. Bit No. 2, nm on a 1.5 degree directional assembly, was then used to drill ahead. High background gas readings were encountered after penetrating a clay rich zone from 2,915' to 2,975' reaching a maximum value of 4,327 units at 2,955'. This zone appeared to contain gas hydrates as high background and high connection gas readings were persistent for the remainder of'the 8.5" interval. This interpretation was made deeper in the well where connection and trip gas peaks were consistently lagged fi:om just below the 9 5/8" casing shoe. A significant oil show was logged in a sand extending fi-om 3,025'-3,100' in the Ugnu Formation.. Hydrocarbon shows that were logged from this sand indicated the presence of oil even though chromatograph breakdowns of the gases encountered were predominately methane. A short.trip was made at 4,454' to condition the hole pulling the bit back to the 9 5/8" shoe. After drilling ahead, the maximum gas recorded from this trip was 4,753 units. Moderately high background gas and connection gas readings continued while drilling in the Ugnu Sands to a depth of 4,400' maintaining the mud weight at 9.6/9.7 ppg. All shows of fluorescence logged in these sands were believed to be associated with low gravity oil. Another short trip was performed at 4,458' to condition the hole. The maximum gas recorded after drilling continued with Bit No. 2 was 4,753 units. A significant change in the type of background gas was noted drilling through sand and. siltstone below this depth. Chromatograph breakdowns from high background gas readings contained good quantities of ethane though pentane. In addition, shows of oil fluorescence improved considerably in intensity indicating the presence of lighter gravity oil. High background gas and fair quality oil shows were logged in one zone in the lower Ugnu Formation extending from 4,605'-4,660'. The West Sak sands logged below 4,700' exhibited oil shows of poor quality mainly because of poor porosity estimates. The lithology changed to predominately siltstone below the sands in the West Sak Formation. A short trip back to 4,500' was performed at 5,979' to condition the hole. The maximum gas reading from bottoms up was 2,280 units. Below 6,050' the lithology change to shale. Drilling continued with Bit No. 2 occasionally sliding to reduce the angle as directed by the well plan. The mud weight was raised to 10.2 ppg by 6,900', to 10.7 ppg by 7,050', and to 11.3 ppg after reaching 7,062'. The mud weight was raised to counter the anticipated formation pressure expected in the Kupamk Sands. After encountering a resistivity increase recorded at 7,020', drilling was suspended at 7,062' on the conclusion of' having reached core point. The hole was circulated out at this juncture. The evaluation of the drill cuttings circulated from bottom indicated that about 40' of the Kupan~ had been penetrated. Very good shows of oil fluorescence and cut were logged in sandstone cuttings from 7,020'-7,062'. The maximum gas recorded from this section was 4,130 units from 7,050'. After weighting the mud system to 11.3 ppg the hole was conditioned with a short trip to 4,583'. The maximum trip gas recorded from the short trip was 5,195 units. The hole was then displaced with 11.3 ppg - 6% KCL coting fluid. Two more short trips, along with additional circulating time to condition the mud were made prior to pulling out of the hole with Bit No. 2. The maximum trip gas readings from both trips were 1,093 and 910 units respectively. Bit No. 3 was made up on a 60' core barrel and run into the hole to 2,934'. The assembly could not be worked through a tight spot at this depth and was pulled out of the hole. A hole opener was then run into the hole and used to wash and ream through 2,950'-3,075'. This assembly was nm into the hole and hit another section of tight hole at 4,310'. The hole opener was plugged at' this depth and had to be pulled out of the hole to be Cleaned. The hole opener was then run in the hole ' to 6,956' and used to wash and ream to bottom. The maximum gas reading on the trip was 2,140 units. A 60' core barrel assembly was again run into the hole. Two tight spots at 3,265' and 4,025' were washed and reamed on the trip in. After running the rest of the way into the hole, the hole was conditioned with circulating out the hole and a short trip to 6,085' prior to starting Core No. 1. Core No. 1 was cut from 7,062'-7,115' and recovered 51' of formation. A second bit was again run in the hole. Core No. 2 was cut from 7,115'-7,134' and recovered 19' of formation. Background gas readings for both core runs were moderate averaging 250-400 units. RR Bit No. 2, a PDC type bit, was run into the hole after laying down the last core. This bit was used to drill the remainder of the 8.5" interval to the total depth of 7,583' for NWE 1-02 on 3-21- 98. Moderate background gas readings and poor shows of fluorescence were logged throu~a this section. The hole was then conditioned with a short trip back to 6,980' recording a maximum trip gas reading of 1,027 units fi.om the hydrate zone at 2,950' and 290 units from bottom. RR Bit No. 2 was pulled out of the hole and the well was evaluated with wire line logs. Upon the successful completion of wire line logs, a 7" liner was run and cemented in the hole in preparation to flow test the well. Analysis fi'om gas readings and cuttings fluorescence taken in the Ugnu indicated the presence of low gravity oil in individual zones primarily in the upper part of this formation. This evaluation changed somewhat after penetrating into the lower Ugnu, which appeared to contain lighter gravity oil. Although the overall show rating for this zone was poor, this was mainly due to poor porosity estimates. The oil in the sands below 4,600' appeared to be of fairly good quality, particularly between 4,610'-4,675' Four show reports were filled out for the 8.5" interval of this well relative to the targeted zone of interest. Good oil shows of fluorescence and cut were recorded in drill cutting samples collected in this interval. Ratio analysis fi'om gas readings taken in this zone indicated the presence of oil although the analysis was somewhat difficult in that gas coming fi:om the hydrate zone at 2,950' appeared to influence the analysis. Please refer to the Show Report Section of the report for additional information. The lithologies of this section consisted of gravel, sand, clay, siltstone, shale, sandstone, coal, and thin tuff beds. Abnormal gas readings were encountered in this section relative to the hydrate zone drilled from 2,920'-2,990'. This zone made evaluations of shows and pore pressure estimates more difficult in that gas was continuously being introduced to the borehole. High background'gas readings were logged in the Ugnu and the Kupamk Formations where hydrocarbon shows were prevalent. The pore pressure estimate for this section of the hole ranged from 8.7 to 9.7 ppg establishing an increasing gradient below 5,100'. Hole problems for the interval were moderate and were mostly associated with problems encountered with tight hole conditions prior to coring the target. PORE PRESSURE: CONCLUSIONS Pore pressure estimates for this well were made genen relative to the current mud weight in conjunction resistivity data. "Dc" Exponent data for this well extensive use of PDC type bits. NWE 1-02 appeared to be near normally pressured Using the Condensed Resistivity Plot (refer to Se( increasing pore pressure gradient is believed to start at increased to a maximum estimate of 10.2 ppg for the on this location was drilled with 11.3 ppg mud. Th NWE #1-01. ZONES OF INTEREST: th ¸pt Good shows of oil cut fluorescence were first noted o 3,025' in the Ugnu. These shows lacked primary flu, background readings were recorded in the upper Ug~ line gas readings were predominately methane. This 1 .!e low recorded amounts of C2-C5 gases, indicated th Ugnu Sands. Good shows of fluorescence were logged in the lowe: to 4,675'. This zone had much better quality of readings, and very good ethane through pentane background gas. In our opinion, the presence of the~ indicator that the oil in this zone has not undergone found in the upper Ugnu. The West Sak Sands on shows. The primary target for this well was the Kupamk logged between 7,020'-7,060' with good porosity Unfortunately, this section of the hole was not core drill cuttings in this zone indicated the presence of m The cored section of the Kupamk also exhibited fair section of the hole between 7,060'-7,090' may al! readings suggest that the zone might be oil bearing,' ~e GENERAL: The drilling program for NWE 1-02 was designed to penetrate to an estimated measured depth of 8,000' and evaluate sands located in the Kuparuk Formation predicted below 6,500' true vertical depth. This well is now one of four wells that have been drilled in this area to evaluate the Northwest Eileen Prospect. NWE 1-02 was drilled to 7,583' in 13 days and reached the projected total depth for the hole close to the 12 days originally estimated to drill this well. A 7" liner was run and cemented in the hole on 3-25-98 in preparation to flow test the well. Hole problems that were experienced in the upper part of the well consisted of high background gas encountered while drilling through hydrates. The gas hydrates drilled on this well did not cause adverse drilling problems and was handled safely by the rig crews. Using gas background gas and resistivity data, there appear to be several zones that possibly contain hydrates extending fi.om 1,800'-2,050', 2,100'-2,175', 2,300'-2,450', and 2,920'-2,990' respectively. The last zone that was suspected to contain hydrates did cause some problems in evaluating the well fi'om the standpoint of using mud gas readings. While drilling in the 8.5" interval, high connection and trip gas readings were consistently logged fi.om this zone. This persistent exposure of gas fi.om up hole hampered pore pressure estimates and show evaluation analysis and was one of the causes for additional circulating time on some of the trips. The surface casing on this well needed to be about 175'-200' deeper to control this situation. In the deviated section of the hole, the angle build and drop was performed adequately as only minor amounts of drag were experienced on trips - excluding the trip in the hole to core. The probable causes for the problem on the trip to core included the rapid build up of mud weight at the core point and the change out to a new mud system. One thing in addition, the rig did not trip all the way out of the hole to the shoe on any of the wiper trips to condition the hole prior to the first attempt to core. The kick off point for this well was started in the first well bore interval below 450'. From here, the hole angle was gradually built io an average of 27 degrees and an azimuth of 42 +/- degrees by 2,600 '. This angle and direction was maintained until 6,000' were the angle was dropped to an average of 9 degrees by 7,400'. Good penetration rates were observed on this well with the proper use of rock and PDC type bits while drilling through a variety of different types of formations. One PDC bit was used to drill the entire 8 V2" interval - over 4,669' of formation excluding the two core hms. the high probability of some of the gas coming from up hole (2,950') in the hydrate zone. Resistivity readings for this section were low averaging 5-6 ohm-m suggesting low porosity or some water saturation. Please refer to the Show Report Section of this report for more details. The remainder of the Kupamk Formation was logged with moderately low background gas and poor quality oil shows. '= ROTATING HOURS vs. DE? 50 100 MB X." ~.,- x." ~ '. 3888 ~888 5888 . 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I, [. ,. sperry--sun LOGGING SYSTEMS BIT RECORD CASING PROGRAM 2O 9 5/8 inch at inch at inch at inch at inch at 110 2827 COMPANY BP EXPLORATION FIELD/BLOCK PBU WELL NORTHWEST EILEEN #1-02 LOCATION SEC 34 - T12N - R11E CONTRACTOR NABORS ALASKA DRILLING STATE ALASKA MUD COMPANY BAROID DRILLING FLUIDS SPUD DATE 3-09-98 BIT SIZE JETS DEPTH FEET ROP HRS TOT CST WOB RPM FLOW SSP MW GRADE REMARKS DATE NO, TYPE inches 1/32 OUT drlg ft/hr HRS $/ft klbs gpm psi PPg I 0 D L B G 0 PLtLED 03-11-98 1 MO250D 12.25 12-12-12-12 2842 2732 156 17.5 17.5 45 20/30 165 565 1750 10. 2 5 4 BT A E i N 0 TD 03-16-98 2 D$7OFGNPV 8.5 6x12'$ 7062 4220 145 29.1 46.6 50 10/15 330 535 2150 9.7 5 4 BT A NA I NO CP 03-18-98 3 ARC 412C3 8.5 .77TFA 7115 53 24.1 2.2 48.8 NA 5/10 80 290 1150 11.5 - JCB 03-19-98 4 ARC 425 8.5 .75TFA 7134 19 12.5 7.5 56.5 NA 10 80 290 1200 11.3 - JCB 03-21-98 RR2 D$7OFGNPV 8.5 6xl 2'S 7583 449 25.8 17.4 73.9 449 15/25 185 535 2450 11.3 5 4 BT A NA I N 0 TD ,,,, sperry--su n LOGGING S' YS TEMS CASING PROGRAM 2O 9 5/8 inch at inch at inch at 110 It 2827 It DRILLLING MUD RECORD inch at inch at COMPANY BP EXPLORATION FIELD/BLOCK PBU WELL NORTHWEST EILEEN #1-02 LOCATION SEC 34 - T12N - R11E CONTRACTOR NABORS ALASKA DRILLING STATE ALASKA MUD COMPANY BAROID DRILLING FLUIDS SPUD DATE 3-09-98 DATE DEPTH WEIGHT VIS PV YP GELS FLTR HTHP CAKE SOL OIL WATER SD CEC pH PM Pf/Mf CI- CA 10 sec/ 1 998 ft lb/gal sec cp Ib/hf2 10rain ml/30ff /deg F 1/32 % % % % meq/hg ppm ppm 03-10-98 1416 10.2 152 22 36 13/59 14,4 3 8 1 91 1,0 22,2 8.5 .10 .05/,50 700 40 , 03-11-98 2848 10.3 81 20 20 7/28 8.5 2 12 0 88 2,5 20 9.2 .30 .15/,65 600 48 03-12-98 2848 10.3 56 22 6 3/10 11,0 2 9.9 0 90 1,5 17.5 9.8 .60 .30/.90 1000 220 0.3-13-98 2862 9,6 59 20 24 6/8 7.6 1 3.9 0 94 TR 10 9.1 .15 .06/.25 37000 100 03-14-98 5009 9,6 59 12 27 7/13 7.0 1 4.4 1 93 .5 12,5 9.6 .65 .30/,80 28000 80 03-15-98 6690 9.7 64 19 24 6/16 5.5 2 4.3 1 93 .25 17,5 8.8 .35 .10/,90 30000 100 03-16-98 7062 11.3 122 36 33 6/14 2.2 6,6 1 10,4 1 87 0 7.5 8.6 1,0 00/.20 30000 120 03-17-98 7062 11,4 150 44 39 8/17 2.3 8.2 1 11,4 1 86 TR 12,5 8.5 1.15 00/.20 31000 260 03-18-98 7062 11.6 197 47 44 9/19 2.0 17.4 1 12.4 1 85 ,25 12.5 8.5 1.4 00/,20 31500 280 03-19-98 7116 11.5 163 45 39 8/18 2,4 7,0 2 13.4 1 84 .5 12,5 8,2 1.4 00/.40 31000 280 03-20-98 7134 11,3 148 44 42 8/18 2,3 7,6 2 13.4 1 84 ,25 12,5 8.3 1,1 00/.40 30500 260 03-21-98 7446 11.3 89 34 32 6/13 3.0 7,4 I 12.4 1 85 .25 12.5 9.1 1.4 .10/,50 30500 lZ 03-22-98 7583 11.4 81 33 29 6/14 3.0 8,1 2 11.4 1 86 ,25 12.5 8.9 1.0 .10/,60 30000 120 03-23-98 7583 11.4 82 27 26 5/11 3.1 9.0 1 11.5 I 88 .25 12,5 8.7 ,90 .05/,70 29500 140 L'~I I~ il I lili%:~ I[1_ [:~ J Anadrill Client: BP Exploration Field: Prudhoe Bay Well Name: NWE 1-02 APl number: 50-029-22865 Job Number. 4CX)02297 Rig: NABORS 18E County: NSB State: AK Survey Calculations Calc method for positio Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum MSL Depth reference Drill Floor, 75.70 FT GL above Permanent 46.70 FT KB above Permanent 77.20 FT DF above Permanent 75.70 FT Vertical section odgin Latidude (+N/S-): Departure (+ENV-): Azim from rotary table to target: Mi +70.35050641 -149.32615020 42.90 degrees Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth # Depth angle angle (ft) (deg) (deg) 1 0.00 0.00 0.0 2 116.49 0.10 19.9 3 215.54 0.15 36.8 4 3O8.83 0.46 55.3 5 401.11 0.77 43.5 6 492.93 1.50 37.5 7 582.39 2.58 35.0 8 673.67 4.34 35.6 9 770.32 7.22 38.2 10 861.60 9.61 42.0 11 952.80 11.70 42.4 12 1044.63 14.21 42.4 13 1137.45 16.83 43.1 14 1230.44 18.47 42.2 15 1323.01 18.92 43.4 16 1416.11 20.41 43.1 17 1507.04 21.81 40.4 18 1602.17 21.57 40.8 19 1695.24 22.38 38.7 20 1787.59 22.60 40.4 SURVEY REPORT Course TVD Vertical length depth section (~) (ft) (ft) 0.0 0.00 0.00 116.5 116.50 0.09 99.0 215.50 0.30 93.3 308.80 0.79 92.3 401.09 1.77 91.8 492.87 3.58 89.5 582.32 6.75 91.3 673.45 12.21 96.6 769.55 21.89 91.3 859.86 35.23 91.2 949.48 52.09 91.8 1038.94 72.66 92.9 1128.44 97.52 92.9 1216.96 125.68 92.6 1304.68 155.38 93.1 1392.35 186.69 90.9 1477.15 219.41 95.2 1565.61 254.57 93.0 1651.86 289.30 92.4 1737.23 324.56 Spud Date: Last survey date: Total accepted surveys: MD of first survey: MD of last survey: 09-Mar-98 21 -Mar-98 81 116.49 7505.05 FT FT Geomagnetic data Magnetic Model: Magnetic Date: Magnetic field strength: Magnetic dec (+ENV-): Magnetic Dip: BGGM 1996 Version 35794.00 1146.50 HCNT 27.99 degrees 80.69 degrees MWD Survey Reference Criteda Reference G: 1002.68 mGal Reference H: 1145.87 HCNT Reference Dip: 80.68 degrees Tolerance G: 4.00 mGal Tolerance H: 6.00 HCNT Tolerance Dip: 0.30 degrees Correction Magnetic dec (+ENV-): 27.859 degrees Grid convergence (+ENV-): 0.00 degrees Total az corr (+ENV-): 27.859 degrees Displacement Total at Azm . DLS +N/S- +ENV- displacement (deg/ (fi) (fi) (fi) (deg) lO0f) 0.00 0.00 0.00 0.00 0.00 0.10 0.03 0.10 19.90 0.09 0.28 0.14 0.31 26.78 0.06 0.59 0.52 0.79 41.46 0.34 1.25 1.25 1.77 45.04 ,0.36 2.65 2.41 3.58 42.25 0.80 5.23 4.28 6.76 39.27 1.21 9.73 7.47 12.26 37.52 1.93 17.47 13.35 21.99 37.39 2.99 27.64 22.00 35.33 38.52 2.69 40.13 33.33 52.17 39.71 2.29 55.33 47.21 72.73 40.47 2.73 73.57 64.09 97.57 41.06 2.83 94.29 83.16 125.73 41.41 1.79 116.07 103.33 155.40 41.68 0.64 138.89 124.80 186.72 41.94 1.60 1 63.32 146.57 219.45 41.91 1.87 190.04 169.47 254.62 41.73 0.30 216.78 191.70 289.39 41.49 1.20 244.02 214.20 324.69 41.28 0.75 Page 1 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course 'I'VD Vertical Displacement Total at Azm DLS # Depth angle angle length depth section +N/S- +ENV- displacement (degJ (fi:) (deg) (deg) (fi) (ft) (fi:) (fi:) (fi:) (fi:) (deg) lOOf') 21 1878.88 22.44 40.2 91.3 1821.57 359.50 270.69 236.81 3,59.66 41.18 0.19 22 1972.53 22.18 41.4 93.6 1908.17 395.00 297.59 260.03 395.19 41.15 0.56 23 2063.35 22.39 41.6 90.8 1992.18 429.42 323.38 282.84 429.62 41.17 0.25 24 2156.04 22.17 41.6 92.7 2077.96 464.56 349.66 306.18 464.76 41.21 0.24 25 2248.89 23.29 42.2 92.9 2163.65 ,500.45 376.37 330.15 500.66 41.26 1.23 26 2341.60 24.26 42.1 92.7 2248.48 537.82 404.08 3,55.23 538.02 41.32 1.05 27 2433.74 25.53 41.2 92.1 2332.02 576.58 433.05 380.99 576.79 41.34 1.44 28 2528.08 26.33 42.5 94.4 2416.92 617.85 463.79 408.53 618.07 41.38 1.04 29 2619.93 27.93 42.4 91.8 2498.61 659.71 494.68 436.79 6,59.92 41.44 1.74 30 2712.19 27.77 42.7 92.3 2580.22 702.82 526.45 465.94 703.03 41.51 0.23 31 2756.92 27.57 42.2 44.7 2619.81 723.58 541.76 479.95 723.78 41.54 0.69 32 2857.73 27.79 41.6 100.8 2709.07 770.40 576.62 511.22 770.61 41.56 0.35 33 2958.92 28.02 41.2 101.2 2798.51 817.74 612.14 542.54 817.97 41.55 0.29 34 3052.16 27.83 40.7 93.3 2880.94 861.41 645.14 571.18 861.66 41.52 0.32 35 31 44.68 27.79 41.2 92.5 2962.76 904.54 677.74 599.47 904.81 41.49 0.26 36 3236.63 27.45 40.8 91.9 3044.19 947.12 709.89 627.42 947.42 41.47 0.42 37 3329.85 28.10 39.4 93.3 3126.74 990.54 743.15 655.42 990.88 41.41 0.99 38 3423.34 28.79 38.5 93.4 3208.86 1034.93 777.75 683.38 1035.33 41.30 0.87 39 3516.09 28.11 37.9 92.8 3290.45 1078.99 812.49 710.72 1079.47 41.18 0.79 40 3608.23 28.39 37.4 92.1 3371.58 1122.39 647.00 737.35 1122.99 41.04 0.40 41 3702.68 27.28 44.9 94.5 3455.18 1166.42 880.20 766.29 1167.03 41.04 3.88 42 3797.08 26.68 44.5 94.4 3539.30 1209.22 910.64 796.41 1209.77 41.1 7 0.66 43 3891.08 26.13 44.0 94.0 3623.49 1251.01 940.59 825.59 1251.52 41.27 0.63 44 3983.14 26.87 46.8 92.0 3705.83 1292.01 969.39 854.82 1292.45 41.41 1.58 45 4075.96 26.81 47.4 92.9 3788.72 1333.84 997.94 885.54 1334.19 41.58 0.30 46 4170.23 26.81 47.2 94.2 3872.80 1376.21 1026.76 916.77 1376.48 41.76 0.10 47 4263.90 27.05 46.8 93.7 3956.34 1418.53 1055.70 947.80 1418.74 41.92 0.32 46 4358.81 27.11 45.9 94.9 4040.83 1461.66 1085.52 979.06 1461.82 42.05 0.44 49 4451.11 27.83 45.9 92.3 4122.73 1504.17 1115.15 1009.63 1504.30 42.16 0.78 50 4545.28 28.22 46.2 94.2 4205.88 1548.37 1145.87 1041.50 1548.46 42.27 0.44 51 4637.93 28.31 45.0 92.6 4287.44 1592.17 1176.55 1072.83 1592.24 42.36 0.62 52 4730.80 28.26 44.8 92.9 4369.25 1636.16 1207.73 1103.90 1636.22 42.43 0.12 53 4823.20 28.39 44.9 92.4 4450.58 1679.98 1238.81 1134.82 1680.02 42.49 ' 0.15 54 4914.55 28.59 44.4 91.4 4530.92 1723.55 1269.83 1165.46 1723.59 42.55 0.34 55 5009.22 28.67 44.5 94.6 4613.95 1768.87 1302.18 1197.20 1768.89 42.59 0.10 56 5103.59 28.46 43.2 94.4 4696.86 1814.00 1334.73 1 228.47 1814.02 42.63 0.70 57 5198.68 28.27 43.0 95.1 4780.54 1859.18 1367.72 1259.34 1659.19 42.64 0.22 58 5289.92 28.11 42.1 91.2 4860.92 1902.26 13,99.46 1268.48 1902.28 42.64 0.50 59 5383.61 27.66 41.6 93.7 4943.74 1946.07 1432.10 1317.72 1946.10 42.62 0.54 60 5478.32 27.17 41.4 94.7 5027.81 1989.66 1464.76 1346.61 1989.69 42.59 0.53 61 5569.90 27.06 39.9 91.6 5109.34 2031.38 1496.43 1373.80 2031.41 42.55 0.76 62 5663.61 27.06 41.2 93.7 51 92.79 2073.96 1528.82 1 401.51 2074.01 42.51 0.63 63 5756.15 26.78 44.8 92.6 5275.36 2115.87 1559.47 1430.09 2115.92 42.52 1.79 64 5849.01 26.35 44.5 92.8 5358.36 2157.35 1588.99 1459.26 2157.39 42.56 0.49 65 5941.67 25.80 43.9 92.7 5441.62 2198.09 1618.20 1487.66 2198.12 42.59 0.66 66 6035.59 25.22 44.1 93.9 5526.37 2238.52 1647.29 1515.76 2238.55 42.62 0.62 67 6128.72 24.12 42.3 93.1 5610.97 2277.37 1675.61 1 542.36 2277.40 42.63 1.43 68 6221.27 22.60 43.1 92.60 5695.98 2314.09 1702.59 1 567.25 2314.11 42.63 1.68 69 6316.12 20.31 41.0 94.80 5784.21 2348.75 1728.32 1590.50 2348.78 42.62 2.55 Page 2 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD # Depth angle angle length depth (ft) (deg) (deg) (fi) (ft) 70 6409.09 18.85 41.7 93.00 5871.83 71 6502.72 18.11 41.0 93.60 5960.60 72 6596.11 15.37 41.6 93.40 6050.03 73 6689.61 13.90 37.1 93.50 6140.50 74 6783.21 13.50 35.6 93.60 6231.44 75 6878.29 11.48 38.6 95.10 6324.28 76 6967.36 9.75 44.0 89.1 6411.86 77 7065.11 9.81 43.0 97.7 6508.14 78 7165.65 9.96 42.1 100.5 6607.14 79 7258.62 9.75 41.7 93.0 6698.77 80 7352.6 9.42 42.8 94.0 6791.46 81 7445.71 8.63 42.6 93.1 6883.38 82 7505.05 8.74 41.6 59.3 6941.98 Projected 7583.05 8.74 41.6 78.0 7019.08 vertical Displacement section +N/S- +ENV- (ft) (ft) (ft) 2379.90 1751.72 1611.08 Total displacement (ft) 2379.94 at Azm (deg) 42.61 2409.56 1773.98 1630.69 2409.60 42.59 2436.45 1794.20 1648.43 2436.49 42.58 2460.01 1812.43 1663.43 2460.08 42.55 2482.03 1830.28 1676.57 2482.10 42.49 2502.48 1846.70 1688.94 2502.56 42.45 2518.87 1859.06 1699.72 2518.95 42.44 2535.47 1871.10 1711.14 2535.55 42.44 2552.72 1883.81 1722.80 2552.80 42.44 2568.63 1895.65 1733.44 2568.71 42.44 2584.28 1907.24 1743.96 2584.37 42.44 2599.05 1918.09 1753.97 25,99.13 42.44 2608.10 1924.81 1760.04 2608.19 42.44 2619.95 1933.67 1767.91 2620.04 42.44 DLS (deg/ 1.59 0.83 2.94 1.99 0.57 2.23 2.24 0.18 0.21 0.24 0.40 0.63 0.30 0.00 Page 3 SHOW REPORTS This section of the report contains copies of show evaluation reports for NWE 1-02. These reports are based on chromatograph evaluations of gases normally retrieved from mud samples injected into Sperry-Sun's Steam Still apparatus; consequently, interpretations made on each report reflect this procedure. Show reports are not alwaYs included in the well report analysis because of restricted information requirements placed on some wildcat wells. They do offer some insight of fluid content on potential producing zones of good permeability; however, they are often inadequate on tight zones or when mud-gas samples are taken while, coting. See attachment regarding SPE-AIME, B.O. Pixler referencing hydrocarbon ratio evaluations. ~. ~ ~' R R ¥ =' ~ U ,.~. LEGEND ~R ~o Bet,J~n~ ,~0 C~Pcul~t~ Out LhT Lo,~ ~MM~R~Y -- ~.I.D. ~H~L~SIS F,I,D, OHROM~TO~RSPH ~RP I) ~ ~ E. ~.R. 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T. ~,~ t -- ........................... t ' ~. /~ I . ,................... ~ ................... ~ ........... ~ ................................. ~ ,' ..... ~ ...................... ~ .................................................................................................... ~ ................................................. ~ .......................... l .......... ~,-.,¢' ......................... ~, ............ . ,.. ............................... ~ ,, '~. ,. ~ ~., ~,. L f, ~.~ ,' ........... ~ %,~ ~:~'Uf ':~'~ "~:U'~ '~:~: L ~ ~ ~,/~ I I, ~ ~ ) I, .................... ',.-....~-~:.................... .~. ............. , .' ...... ~ ....................... ,,. ........................ ~ ......................................................... ~.~ ............................... ,,.....~ ....... ~....~ .................. ............. ~-~ F.-,,~ ~ I, ~ .......... ~ ~ ................ '1 ~' ~ ~ ' ~ ~ ' - ' - FLU~ R.BRH STH.~ CUT.ST ~ i ~ . ' ........... ! ' ' ............................ ~ i. ~ 1, L " , , ff i I I ~- ~. ~ r. ' ........... ~'~ ............................... t ', ~. ~. ~ ~. ~. ~ / ~ I'~' ~ ~ ........... H., ................................... ~ ~ ~. ~' ~' ','/ / I ~ ~ ..... sperry--sun LOGGING SYSTEMS A D~ESS~ I'~USTP~S COIV~ANY Operator SHARED SERVICES DRILLING Well Name NORTHWEST EILEEN #1-02 Location NORTH SLOPE, ALASKA Sh. Report 2 Part B Depth Interval 7025 to 7065 True Vert. Depth 6469 to 6507 Prepared by D. WALTERS Delivered to J. RAY Date 15-MARCH Time 2:30 PM ZE~NE ~CTION CONTACT DEPTH l-I I 10,L CI r-I Gas/Oil ft. Gas/Water NON-PRODUCIBLE HYDR(X~ARBONS ft. Oil/Water ft. ,5 I DEPTH 7028 r--i% ft. GAS [~] units 2800 MUD CHLORIDES (ppm) 30000 F LOWLINE SUOTION S HOW ,.-. ppm ppm ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C I 42r500 _ 2r980 ._ 39r520 C 1/C 2 -" 8 C 2 5,1 O0 - 286 -- , 4~814 C /c - 10 C 3 4,100 - 131 -- 3, 969 I 3 -- C 4 3,740 . 216 -- 3,524 C ~ /c 4 = 11 c 5 2~732 _ 168 -- 2~564 c 1 /c 5 = 15 PRODUCTIONANALYSIS F-'~GAS r'~OIL r-]WATER O NON-PRODUCIBLEHYDROCARBONS- r-i% DEPTH 7038 ft. GAS r'~ units 3300 MUD CHLORIDES (ppm) 30000 FLOWLINE ppm C I 89,000 C 2 9,200 C 3 6~450 C 4 5,05O C 5 3,315 SUCTION SHOW _._ ppm ppm (Steam Still ppm's in lO00's) HYDROCARBON RATIOS 2,980 86,020 C C -" 1/ 2 -' 10 286 -- 8, 914 c~ /c3 = 14 131 --' 6~ 319 c 18 216 __-- 4,834 I /C 4 "- 168 -- 3,147 -- 27 Cl/C5 PRODUCT,ONANA,YS,S I--IGAs 1310" I--]WATER UTHOLOGY r'-] NONIPRODUCIBLE HYDROCARBONS ' SANDSTONE-CLEAR QUARTZ, LIGHT-MEDIUM GRAY. BLACK. GREEN. VERY FINE TO FINE GRAIN. OCCASIONAL FLOATING COARSE GRAIN. SUBANGULAR TO SUBROUNDED. MODERATELY SORTED. PREDOMINATELY UNCONSOLIDATED. TRACE WITH HARD NON CALCAREOUS CEMENT. GLAUCONITIC IN PART. SHOW EVALUATION 40% DULL TO MODERATELY BRIGHT ORANGE FLUORESCENCE IN 7040' SAMPLE WITH FAIR YELLOW STREAMING CUT FLUORESCENCE. STRAW CUT. OIL STAIN. REMARKS FORMATION GAS SAMPLES COMTAIMNATED WITH HIGH C1 FROM CONNECTION GASES UPHOLE IN THE UGNU~ HOWEVER THE STEAM STILL ANALYSIS AT 7028' INDICATES THIS ZONE TO BE OIL BEARING. THIS IS DEEMED TO BE A GOOD OIL SHOW. HYDROCARBON RATIOS C1 C1 C1 C1 C C lO 8 6 4 3 2 1 HYDROCARBON RATIOS C1 C1 Cl C1 C C NONP :~ODUC' IVE i .. LOGGING SYSTEMS A DI~_SSi~ I'~USTF~S ~ANY Operator SHARED SERVICES DRILLING Well Name NORTHWEST EILEEN #1-02 Location NORTH SLOPE, ALASKA Sh Report 3 Part B Depth Interval 7025 to 7065 True Vert. Depth 6469 to 6507 Prepared by D. WALTERS Delivered to J. RAY Date 15-MARCH Time 2:30 PM 2~NE t ~_[~a~j~GAS· r~ OIL ff. [--~WATER Gas/Water PRODUCTION ............... CONTACT i: - - NON-PRO~CIBLE HYDROCARBONS ff. Oil/Water ff. % DEPTH 7045 ff. GAS ~ units 3800 MUD CHLORIDES (ppm) 30000 FLOWLINE ppm SUCTION SHOW _ -..- ppm ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C I 101,000 _ 2r980 _-- 98r020 C 1/ C 2 '"' 10 C 2 ...lOrO00 _ 286 -- 9~714 cl /c3 = 15 C 3 6,500 - 131 '- 6, 369 C 4 4,800 . 216 -- 4,584 C I /c 4 = 21 C 5 3,136 168 -- 2r968 C I /C 5 -- 33 PRODUCTIONANALYSiS [-']GAS r'~loIL E-~WATER r'-] NON-PRODUCIBLE HYDROCARBONS ., GAS r-] units MUD CHLORIDES (ppm) FLOWLINE SUCTION SHOW ppm ppm ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS Cl _ cl/c -- 2 '- C2 -- C1/C3 C3 C4 _-- 0I /04 = 05 : C1/C5 PRODUCTIONANALYSIS r-]GAS E]OlL r']WATER E] NON-PRODUCIBLEHYDROCARBONS- UTHOLOGY SANDSTONE-CLEAR QUARTZ, LIGHT-MEDIUM GRAY. BLACK. GREEN. VERY FINE TO FINE GRAIN. OCCASIONAL FLOATING COARSE GRAIN. SUBANGULAR TO SUBROUNDED. MODERATELY SORTED. PREDOMINATELY UNCONSOLIDATED. TRACE WITH HARD NON CALCAREOUS CEMENT. GLAUCONITIC IN PART. SHOW EVALUATION 40% DULL TO MODERATELY BRIGHT ORANGE/YELLOW FLUORESCENCE WITH FAIR YELLOW STREAMING CUT FLUORESCENCE. STRAW CUT. OIL STAIN. REMARKS FORMATION GAS SAMPLES COMTAIMNATED WITH HIGH C1 FROM CONNECTION GASES UPHOLE IN THE UGNU, HOWEVER THE STEAM STILL ANALYSIS AT 7028' INDICATES THIS ZONE TO BE OIL BEARING. THIS IS DEEMED TO BE A GOOD OIL SHOW. HYDROCARBON RATIOS C~ C~ C~ C~ I I C C HYDROCARBON RATIOS C1 Cl _Cl Cl C C . NONP :~ODUCFIIVE LOGGING SYSTEMS A DFF_SSER I',J)USTP~S COIV~ Operator SHARED SERVICES DRILLING Well Name NORTHWEST EILEEN #1-02 Location NORTH SLOPE, ALASKA Sh.~ Report 4 Part B Depth Interval 7065 to 7090 True Vert. Depth 6507 to 6532 Prepared by D. WALTERS Delivered to J. RAY Date 15-MARCH Time 2:30 PM ZONE PRODUCTION CONTACT DEPTH Gas/Oil ft. Gas/Water ~ NON-Pf:K)DUCIBLE HYDROCARBONS' ft. Oil/Water ft. I I DEPTH 7070 ft. GAS % J'~J units 250 MUD CHLORIDES (ppm) 30000 FLOWLINE SUCTION SHOW - ~ ppm ppm ppm (Steam Still ppm's in lO00's) HYDROCARBON RATIOS C I 14r400 _ lr050 _ _ 13r350 C 1/ C 2 = 14 C 2 1,040 - 80 -- 960 Cl /c3 = 28 C 3 540 - 65 -- 475 C 4 359 - 102 -- 257 C I /C 4 '- 52 C 5 298 _ 90 -- 208 C I /C 5 -' 64 PRODUCTIONANALYSIS E]GAS J'~'JoIL r-]WATER [] NON-PRODUCIBLEHYDROCARBONS J I-I% 6 DEPTH 7080 ft. GAS J~] units 300 MUD CHLORIDES (ppm) 30000 FLOWLINE SUCTION $ HOW . -.. ppm ppm ppm (Steam Still ppm's in lO00's) C I 24,000 _ 1,050 -- 22,950 C 2 1,770 - 80 '- 1,690 C 3 940 - 65 -- 875 C 4 601 - 102 -- 499 C 5 425 - 90 -- 335 HYDROCARBON RATIOS C1/C2 = 14 c1 /c3 = 26 = 46 C1/C4 Cl/C5 = 69 PRODUCTIONANALYSIS r-]GAS J-~IoIL r'-JWATER r~J NON-PRODUCIBLEHYDROCARBONS LITHOLOGY SANDSTONE- SEE GEOLOGIST CORE LOGS FOR DESCRIPTION. POOR SAMPLE QUALITY WHILE CORING. SHOW EVALUATION NOT AVAILABLE - POOR SAMPLE QUALITY WHILE CORING. REMARKS iNSUFFICIENT DATA FOR CUT EVALUATION. RESISTIVITY RADINGS AVERAGE 5-60HM/M OVER THIS SECTION AND INDICATE POSSIBLE PARTIAL WATER SATURATION OR TIGHT ZONE. GAS READINGS (Cl) ARE CONTAMINATED FROM UPPER ZONE CAUSING RATIO LINE TO SHIFT UP. FAIR OVERALL SHOW RATING FOR OIL. HYDROCARBON RATIOS C1 C1 C1 ,,C1 C C NONPF:IODUC'I iVE , HYDROCARBON RATIOS Cl Cl ,,,cl Cl C, C NONP :IODUC~'IVE , · , UlL ,,, I .... sperry--su LOGGING SYSTEMS A EI~_~ N3USTF~S COIV~ANY Operator SHARED SERVICES DRILLING Well Name NORTHWEST EILEEN #1-02 Location NORTH SLOPE, ALASKA Sh Report 5 Part B DepTh Interval 7065 to 7090 True Vert. Depth 6507 to 6532 Prepared by D. WALTERS Delivered to J. RAY Date 15-MARCH Ti me 2:30 PM PRODUCTION CONTACT DEPTH i-I o,, I-1 W^TE. Gas/Oil ft. Gas/Water NON--P~CIBIF HYDROCARBONS' ft. Oil/Water ft. I-I% DEPTH 7090 ft' GAS r'~ units 400 MUD CHLORIDES (ppm) 30000 FLOWLINE SUCTION SHOW . ppm ppm ppm (Steam Still ppm's in 1000's) HYDROCARBON RATIOS C 1 28~400 _ lr050 _-- 27r350 C 1/ C 2 -- 12 C 2 2,420 - 80 -- 2,340 C /c - 19 c 3 1,480 . 65 -- 1,415 i 3 - C 4 1,027 . 102 = 925 C I /C 4 '- 30 C 5 ..... 640 . 90 -- 550 C I /C 5 --* 50 PRODUCTIONANALYSIS r-]GAS E~OIL r-]WATER r~ NON-PRODUCIBLEHYDROCARBONS DEPTH ft' GAS [-"] units MUD CHLORIDES (ppm) FLOWLINE SUCTION S HOW ppm ppm ppm (Steam Still ppm's in lO00's) HYDROCARBON RATIOS C1 . -- Ci/C/ m 2 '-' C2 . -- C1/C3 -- C3 _ C4 . -- CI /C4 ,-- C5 . = Cl/C5 = PRODUCTIONANALYSIS r-]GAS F"~OIL E'~WATER r-'] NON-PRODUCIBLEHYDROCARBONS LITHOLOGY SANDSTONE- SEE GEOLOGIST CORE LOGS FOR DESCRIPTION. POOR SAMPLE QUALITY WHILE CORING. SHOW EVALUATION NOT AVAILABLE - POOR SAMPLE QUALITY WHILE CORING. REMARKS iNSUFFICIENT DATA FOR CUT EVALUATION. RESISTIVITY RADINGS AVERAGE 5-60HM/M OVER THIS SECTION INDICATE POSSIBLE PARTIAL WATER SATURATION OR TIGHT ZONE. GAS READINGS (C1) ARE CONTAMINATED FROM UPPER ZONE CAUSING THE RATIO LINE TO SHIFT UP, FAIR OVERALL SHOW RATING FOR OIL. lO 8 6 4 3 2 HYDROCARBON RATIOS C1 C1 C1 C1 C C HYDROCARBON RATIOS C1 C1 C1 ¢1 NONP F:IODUC'I 'IVE PIXLER's PREMISES for LOGGING SYSTEMS SHOW EVALUATIONS Formation Evaluation by Analysis of Hydrocarbon Ratios B. O. Pixler, SPE-AIME, Baroid Div. National Lead Co. Introduction Mud logging was first offered commercially in Aug., 1939. This logging method quickly gained favor among many operators because the type of fluid in the formation could be determined within minutes after the formation was drilled. The presence and magni- tude of the methane show was and is the most im- portant factor in mud log interpretation. However this magnitude in some instances was improperly understood, and as a consequence some operators still do not use mud logging, even though the early technique frequently made the difference between a successful well and an abandoned hole. Both the "hot wire" log of gas combustibles in the sample and the percent-of-gas log obtained with the conventional gas trap and the gas chromatograph indicate only that the reservoir in question contains hydrocarbons. These methods do not necessarily indicate the quantitative amounts of the various hydrocarbons in the mud. The addition of a new Steam Still-Reflux gas sam- pling system to gas chromatography enables accurate determination of the composition of the mud gas sample. A knowledge of gas composition makes'.it possible to establish the relationship of methane to the heavier hydrocarbon shows. An awareness of this relationship led to a new, additional mud log inter- pretative technique that permits relating the quanti- tative amounts of methane (C~), ethane (C._,), pro- pane (Ca), butane (C,), and pentane (C0 to in-place reservoir fluid content. A long-accepted premise is that as formations are drilled, the drilling mud filtrate partially flushes the formation fluid ahead of the bit. It was generally thought that the formations were flushed to an irre- ducible minimum -- generally considered to be about 30 percent of in-place fluid. Experience in mud log- ging, however, has shown that this rarely happens. This partial flushing does not prevent mud logging from successfully determining productive or non- productive formations. Experienced logging engi- neers, in possession of quantitative gas analyses, make interpretations that take into account the flushing that results in rocks of various permeabilities, the effect of overbalanced mud weight and the effect of initial filtrate loss. Method Ordinarily, when formation cuttings are drilled they retain much of the formation pore fluid. This fluid is released to the mud column as the cuttings travel up the annulus. Most of the formation fluid in the cut- tings will be "produced" into the drilling mud during . the top 500 ft of hole travel. Conventionally, a mud sample is diverted to a mechanically operated gas trap to obtain a sample of the gas in the mud. The effi- ciency of this trap is from 15 to 70 percent, depending upon the gel strength of the mud, the amount of mud flowing through the trap and the rotation speed of the trap impeller. The magnitude of the conventional The ratio of methane to the heavier hydrocarbon components ~ ethane, propane, butane, and pentane is indicative of gas, oil and water productive potential. The Steam Still-Reflux Unit, used in conjunction with mud logs and gas chromatographs yields a quantitative analysis from which this ratio can be plotted. gas show is, therefore, qua..,tative only to the air-gas sample obtained. The sample is accurately analyzed by the gas chromatograph; but, because the sample furnished by the conventional gas trap represents only a fraction of the gas present in the mud, and because that fraction is not representative of the total gases in the mud, the results are still only qualitative. When the Steam Still-Reflux Unit is used to obtain the gas sample, the gas sample will represent almost 100 percent of the hydrocarbon fractions C~ through Cz that were in the mud sample. This enables the chromatograph analysis to be related quantitatively to the mud, and the readings to be reported as parts per million of each hydrocarbon vapor (C~ through Cd) to mud volume. · Because the cuttings from a particular formation "produce" the gas they contain into the drilling mud, it was reasonable to assume that this same formation, if completed, would produce gases of a similar eom- position. This assumption led to a comparison of ppm Logs of hydrocarbon vapors with similar data from producing wells. Plots were made of the ratio of methane to each of the heavier hydrocarbons from many analyses of wellhead samples. These plots were compared with plots, made from ppm Logs, of gas in mud. Both groups of plots showed definite patterns between (1) the magnitude of the ratios of methane to each of the heavier hydrocarbons, and (2) the slope of the lines of the plotted ratios. These, in turn, indicate productive potential and reservoir permeability. The Steam Still-Reflux Unit consists of a small steam boiler, mud-injection port, mud-steam mixing chamber, Reflux-Condensing Unit and a gas-extrac- tion port. Five ml of mud are injected into the purged mud-steam mixing chamber. The mud is rolled with 2,000 to 4,000 volumes of steam. The hydrocarbons (C, through C.,) extracted from the mud are collected at the Reflux-,..ondensing Unit, withdrawn with a syringe, diluted to the standard chromatograph sam- ple size and injected into the chromatograph for analysis. The Reflux-Condensing Unit removes only the lighter paraffin series hydrocarbons from the mud sample tested. For example, if the mud contains diesel oil, the more complex hydrocarbons -- CG and above --condense and drop back into the mud-steam mix- ing chamber. Therefore, regardless of whether the fluid phase of the mud is oil or water, the gas sample analyze~l contains only the light fractions through and the analysis is representative of the formation gas. The full importance of determining formation gas composition has not always been apparent. At first it was observed that if the magnitude of butane in the mud was greater than the magnitude of either propane or ethane, the zone in question would pro- duce water and hydrocarbons. Later, the ratios of methane to each of the heavier hydrocarbon com- ponents were plotted on semilog paper. Hydrocarbon ratio plots obtained from ppm Logs and available data from wellhead gas sample analyses were com- pared. The comparison of the plots from ppm Logs and wellhead gas analysis data showed a striking cor- relation. The correlation demonstrated that ppm Logs made with Steam Still-Reflux samples could be in- terpreted in terms of in-place formation content. The magnitude of the methane-to-ethane ratio de-' termines if the reservoir contains gas or oil or if it is nonproductive. The slope of the line of the ratio plot ' of CJC2, Ca/Cs, C~/C4, and C~/C, indicates whether the reservoir will produce hydrocarbons or hydro- carbons and water. Positive line slopes indicate pro- duction; negative slopes indicate water-bearing for- mations. An undersaturated reservoir may show a negative slope, but such occurrences are rare. The ratio plots may not be definitive for low permeability zones, but unusually steep plots indicate tight zones. 4°°[ 300 / 100 ~ ? _ 80 ~, _ 60 20 10 8 3 j C~ C~ C~ C~ C~ C~ C, C~ HYDROCARBON RATIOS MISSISSIPPIAN OIL RESERVOIR SILURIAN GAS-CONDENSATE RESERVOIR (~) ORDOVICIAN GAS-CONDENSATE RESERVOIR LOWER ORDOVICIAN GAS AND WATER Fig./--Hydrocarbon ratio plots obtained from wellhead sample analyses data, limestone reservoirs, Rocky Mountain area. 300: - ! ~ / I . . 200- ~ - '- /_~ i (~)Gas.condensate. FrioSand, ~ ' Hidalgo County, Texas, analysis 14~0~? /~ from wellhead sample. (~) N. Lindsey, 11,000' oil reservoir, analysis from producing well sample. 30~~--''- ~ '-----------! (~ State tract 49 No. 1 well. Nueces 20i - , ; ', ~ County, Texas. 12.690' section, analysis ~.~_~/ from gas show on ~/:)rn Log. ] :, , 1 c, c, c, c, HYDROCARBON RATIOS Fig. 2~Hydrocarbon ratio plots, producbve reservoirs, South Texas. JOURNAl OF PFTROI,FI'M T'FCH'X,'OI A ratio of C,/C: between 2 and 15 indicates oil. A rado of C,/C... between 15 and 65 indicates gas. Thc lower the C:/C... ratio, the richer the gas or the lower the oil gravity. If the rado of C,/C_. is below about 2 or above about 65 the zone is nonproductive. Field Examples Fig. 1 shows average hydrocarbon ratio plots from limestone reservoirs in the Rocky Mountain area. Plot 1 is derived from analyses of gases from Mis- sissippian oil-producing reservoirs. The Cz/C: ratio is 3.5. The slope of thc line is positive and not steep. Plot 2 was obtained from analyses of gases from wells producing gas-condensate from the Silurian. The C~/C.. ratio is 12; the line slope is again positive and not steep. Plot 3 is from gas-condensate wells pro- ducing from the Ordovician. The Cz/C.- ratio is 15 and, again, the slope of the line is not steep; all three plots show slopes favorable for production. Plot 4 shows ratios obtained from an analysis of gas from the Lower Ordovician, which produced gas and water. Thc plot shows a negaQve slope of the secQon from the C:/C4 ratio to the C~/Cs ratio. Many tests have verified the fact that if a ratio plot shows a negative slope, the zone in question is water-bearing. Fig. 2 shows plotted hydrocarbon ratios for pro- ductive reservoirs in South Texas. Plot 1 was made from an analysis of a wellhead sample of gas- condensate produced from a Frio sand, Hidalgo County. The production is rich in liquid hydrocar- bons as indicated by the low C~/C.~ ratio. Plot 2 is from an analysis of a wellhead gas sample from an l l,000-ft oil reservoir, North Lindsey field. The pentane was not reported, but the low C,/C: ratio indicates oil production. Plot 3 was obtained from a gas show at 12,690 ft on the ppm Log of the State Tract 49 No. 1 Well, Nueces County, Tex. Formation tests resulted in gas production. Experience shows that if the C~/C: ratio is above 65 the zone is too tight for commercial production. Fig. 3 shows the ratio plots obtained from ppm Logs on Texas Gulf Coast wells that were nonproductive in the zones of interest. Plot 1 is from the ppm Log of the R. A. Tally No. 1 Well, Victoria County, Tex. The C~/C: ratio was 470. The zone was tested ex- tensively but it was a Iow permeability reservoir that could not be commercially completed. Plots 2 and 3 are from the State Tract 49 No. 1 Well, Nueces County, Tex. Plot 2 was from a sand encountered at about 8,060 ft. The relatively high ratios of C~/C~, Cz/Ca, C~/C~, and C~/C~ indicated that the zone was nonproductive because of the low permeability. This was subsequently verified by testing. Plot 3 was ob- tained from a sand at 9,130 ft. The negative slope of the ratio plot, C~/C.~ to C~/Ca, indicated that the zone was water-bearing. Subsequent formation tests showed water and non-commercial amounts of gas. Plot 4 was obtained from the ppm Log of the Kovar No. 1 Well, Victoria County, Tex. The sand encoun- tered from which the plot was made is at 10,120 ft. The gas show appeared to be good, but a negative slope of the C~/Cs ratio to the C~/C4 ratio was posi- tive identification of a water-bearing formation. Evaluation Technique It is apparent that with this evaluation system, poten- tial production can be accurately predicted. The only significant time lapse between penetration of the formation and evaluation of its productive possibili- ties is the time required to pump the mud from the bottom of the hole to the surface and analyze it by the Steam Still-Reflux and Chromatograph method. Fig. 4 shows the evaluation technique, which may be described as follows. First, record the net increase of each gas com- ponent over the background gas; next, plot the ratios ~ooo. (D 4OOO 3OOO 2000 (~) 1000 800: - 600:' (~) 400 ........... -/ 300 ..... / 200 ............ 4O 4I C, C, C_~ C, ~ c-., c. HYDROCARBON RATIOS R. A. TALLY No. 1 WELL. VICTORIA COUNTY. TEXAS STATE TRACT 49 No. 1 WELL. NUECES COUNTY. TEXAS DEPTH 8060' STATE TRACT 49 No. l WELL. NUECES COUNTY, TEXAS ' DEPTH 9130' A. KOVAR No. 1 WELL. VICTORIA COUNTY. TEXAS DEPTH 10120' Fig. 3--Hydrocarbon ratio plots, nonproductive reservoirs, South Texas--analyses from gas shows on ppm Logs. 400 300- 200 (~) Use only gas increase over --- I ~ background. ] i (~) Plot ratios on lines indicated. [ : (~ Evaluate section for probable : : production as indicated by the plotted ~ curve within the following limits: (a) Productive dry gas zones may show , only C~ but abnormally high C~ only shows are usually indicative of ~ salt water. I (b) If the C,/C~ ratio is Iow in the oil sect;on and the C~/C, ratio is high in the gas section the zone is probably ; nonproductive. ~ i (c) If any ratio (C~/C~ excepte~ ii oil is : used in the mud) is lower than a I : preceding ratio the zone is probably nonproductive, For example, if (~ ~ C,/C, is less than C,/C~ the zone ~s probably wet. (d) The ratios may not be definitive for Iow permeability zones, however steep ratio plots may indicate bght zones. NONPRODUCTIVE 100 -:- -, '° 80' _-"- 6O 40 --GAS 3O 2o , .... ] .... --- 10 8 6 NONPRODUCTIVE ~ C. C~ C_L ¥ C] C, HYDROCARBON RATIOS Fig. 4--ppm Log and report form for evaluation of show. II 'N.'F lt}At) C,/C.., C,/C:,, C,/C,, C,/ . on the ratio lines as indicated. Then evaluate, within the following limits, the section in question for probable production as indicated by the plotted curve' 1. Productive dry gas zones may show only C,, but abnormally high shows of C, only are usually indicative of salt water. 2. If the C,/C_~ ratio is low in the oil section and the C,/C~ ratio is high in the gas section the zone is probably nonproductive. 3. If any ratio (C,/C, excepted if oil is used in the mud) is lower than a preceding ratio, the zone is probably nonproductive. For example, if C,./C~ is less than C,/C:~, the zone is probably water-bearing. 4. The ratios may not be definitive for low perme- ability zones; however, steep ratio plots may indicate tight zones. Application The ppm Log is only one of many tools that are ordinarily used for formation evaluation. But in many instances, the ppm Log has furnished the vital infor- mation necessary to make the final decision on a well. One well drilled in inland waters of Louisiana had what appeared ..., the ppm Log to be a good sand body, but the ppm Log showed only a nominal in- crease in gas. After the sand was penetrated and the well deepened, hole trouble was encountered. No other information of interest was available on the sand. The cost of the side-tracking to investigate the sand was sizable. Tight hole conditions and the low magnitude of the gas show indicated that the sand had good permeability and that possibly formation hydrocarbons had been flushed ahead of the bit. A plot of the hydrocarbon ratios indicated oil produc- tion. Therefore, at considerable expense, the sand was investigated and a new oil field was found. An interesting well recently drilled in St. Martin Parish, La., was the No. 1 St. Martin Bank and Trust located on the southeast flank of the Anse La Butte Dome. A good sand encountered at about 8,000 ft showed 0il, but the negative slope of the ratio plot indicated that the sand was water-beating. The well was deepened to approximately 9,600 ft. One of the partners, a successful independent with a talent for finding oil by "feel" and by prudent use of the latest technology, decided that the formations in which the well was being drilled were tilted to almost vertical. DR ppm LOG HYDROCARBON RATIOS PLOT C_.~ C_L C__k~ C_L C= Ca C4 Cs 1 26 62 78 155 2 8.6 14 59 118 3 5.6 7.4 46 106 4 6.8 9.1 56 130 5 5.4 11 70 193 6 4.5 15 54 254 Fig. 5--ppm Log, and hydrocarbon ratio plots, C_& C_L C._L~ C__~ c4 30 _ 6---/ /5/,1 ~..- ~::> --. /( J Il1 -GAS / ¢ /// LOlL I ~ -~,- NONPRODUCTIVE I I No. 1 St. Martin Bank and Trust Well, St. Martin Parish, La. IC)I~RN.,kl. OF PFTRf31 FI'M TECHNOI.OGY On his recommendaion the well was plugged back to about 7,000 ft and sidetracked. The sand that was drilled at 8,000 ft in the first hole was encountered in the directional hole at approximately 7,400 ft and the entire sand was hydrocarbon saturated. The ppm Log and the ratio plots from the sand in the sidetrack hole are shown in Fig. 5. Table 1 shows the mud gas components related to percent of total gas. In actual practice the ppm gas shows obtained from the ppm Log are not converted to percent of total gas; but note the general decrease in percent methane in the lower section of the sand compared with that in the upper section. The magnitude of the gas show in the straight hole and in the sidetrack hole was significant. An accurate determination, how- ever, of the composition of the gas in both cases led to correct conclusions on the potential productivity of the sand at the different depths in each hole. Note that the ratio Plot 1 at the top of the sand indicates a gas cap. As shown in Table 1, the gas was 93.1 percent methane. Subsequent plots indicated that production would be oil. In each of these cases the C,/C: ratio was less than 9. The lowest ratio, 4.5, is shown in Plot 6, which was made from the show at TABLE 1--MUD GAS COMPONENTS, PERCENT OF TOTAL GAS Depth (ft) C, C: C., C, C: 7,460 93.1 3.6 1.5 1.2 0.6 7,475 82.4 9.6 5.9 1.4 0.7 7,485 74.4 13.3 10.0 1.6 0.7 7,490 78.0 11.4 8.6 1.4 0.6 7,500 77.0 14.3 7.2 1.1 0.4 7,515 76.1 17.1 5.1 1.4 0.3 the bottom of the sand. Another example of the application of the ppm Log is No. 1 State Tract 198 Well, Aransas County, Tex. Many sands were encountered showing the presence of hydrocarbons. The logging crew sub- mitted more than 60 ratio plots to the operator during the drilling of the well. In almost all instances subse- quent information verified the logging engineers' pre- dictions of probable productivity based on the ratio plots. Fig. 6 shows a section of the ppm Log and the ratio plots for this well. The gas composition relating the percent of each gas component to the total gas is shown in Table 2. Gas condensate production is indi- 10100 -- 10200 10300 10400 10500 10600 113O0 ppm LOG DR C~ 100 1OM C, C, .C, C, C2 0.,.3 C4 C5 -N~NPR6DUCfiVE -0Il _ _ NONPRODUCTIVE I I I 400 300 200 100 80 60 40 30 2O 10 8 6 2 1 HYDROCARBON RATIOS ,C, C, C, C, PLOT C2 C3 C4 Cs 1 18 71 84 230 2 20 61 92 102 3 19.5 78 233 310 4 16 93 232 C~ 5 19.3 58 115 185 Fig. 6~ppm Log and hydrocarbon ratio plots, No. 1 State Tract 198 Well, Aransas County, Tex. TABLE 2--MUD GAS COMI~,,,HTION, PERCENT OF TOTAL GAS Depth (ft) C, C~. C., C, C, 10,110 92.0 5.2 1.3 1.1 0.4 10,115 92.0 4.6 1.5 1.0 0.9 10,450 93.3 4.8 1.2 0.4 0.3 10,520 92.8 5.8 1.0 0.4 0.0 11,305 92.3 4.8 1.6 0.8 0.5 cated by the ppm Log and ratio plots as shown. The zones are tight marine deposits--especially the 10,520-ft zone. Plot 4 has the steepest line slope; pentane was not present. The slope of Plot 3 is steep. Plots 2 and 5 show more favorable (less steep) line slopes. The electric log and subsequent formation tests made of each zone indicated probable produc- tion. The well was completed as a gas condensate producer in the 11,300-ft section, which is the section plotted as No. 5. Conclusions Only qualitative shows of hydrocarbons in the mud can be derived from conventional mud logs. If chromatography is used, only a general indication of in-place gas composition is obtainable. Such hydro- carbon shows may be reported as units of gas or percent hydrocarbons or parts per million of gas in the air-gas mixture tested. Only the presence in rela- tive amounts, not the actual quantity, of hydrocar- bons in mud is indicated, and other supplemental information may be necessary to evaluate the forma- tion in terms of potential productivity. However, if the composition of the gas sample obtained from the mud is representative of the in-place formation gas, then the gas analysis is accurate. The use of the Steam Still-Reflux Unit makes possible a report of forma- tion gas composition on the ppm Log. Meaningful ratio plots of gas composition can then be made. Even though many factors affect the amount of reservoir fluid released to the drilling mud, reservoir potential productive capabilities can be determined by a study of the ratio of methane to each of the heavier hydro- carbon components. The hydrocarbon ratio plot is a unique technique and provides the operator with new information for evaluating productive possibilities of exploratory wells. Computer programs involving percent gas in mud (ppm Log) and gas composition are being used in special cases to determine reservoir potential produc- tion. The use of computers in mud log interpretation, although new, will contribute significantly towards a better application of the data shown on the ppm Log. J-l~T Original manuscript received in Society of Petroleum Engineers office Aug. 5, :1968. Revised manuscript received March 5, 1969. Paper (SPE 2254) was presented at SPE 43rd Annual Fall Meeting held in Houston, Tax., Sept. 29-Oct. 2, 1968. ~) Copyright 1969 American Institute of Mining, Metallurgical, and Petroleum Engi- neersp Eric. If~l~l,~NAl Nt-' PF-f'I~NI FI'\! TFC'HNf'ilNGY . , GUIDELINES FOR USING PPM RATIO PLOTS TO EVALUATE HYRDROCARBON SHOWS (REVISED 9/27/89 TO COVER "ME~ ONLY" SHOWS) A show that has only methane or primarily methane CAN be indicative of a productive zone. Many wells in the Gulf of Mexico produce only methane or methane and saltwater. (The commercial productivity of a GAS/SALTWATER well is based on the relative proportions of gas versus saltwater saturations determined by resistivity measurements.) a) Fill out a SHOW REPORT in a zone that meets the requirements of a show based on the definition even if it contains methane only. b) c) State in the LOGGER'S OPINION that this is a "methane only" show. Also state that C1 only CAN be indicative of dry-gas production BUT usually has saltwater associated with it. cl) After making the ppm plot and observing for a negative slope, checking _ for a chloride increase (by titration or conductivity) OR observing a r_esistivitv decrease on an MWD log, appropriately "X" the GAS or GAS and WATER indication in the ZONE PRODUCTION AN-AI..YSIS · paragraph on page 1, including the depth of the water contact if detectable and the footage of the show. C1/C2 between 2 and 15 indicates OIL. You should see some fluorescence in the mud or cuttings but not necessarily. a) b) 'Values in the range of 2 - 4 indicate Iow gravity oil (10 - 15 on the APl gravity comparison scale.) A low gravity oil can have a bronze, brown or dull orange fluorescence and be very dark brown to black in color. Values in the range of 4 - 8 indicate medium gravity oil (15 - 35 on the APl gravity comparison scale.) A medium gravity oil will have a cream to bright yellow fluorescence and be light to medium brown in color. ¢) Values in the range of 8 - 15 indicate high gravity oil (35+ on the APT gravity comparison scale.) A high gravity oil will have bright blue to blue-white fluorescence and be clear in color. SEE NOTE BELOW. C1/C"- ratios in the 15 to 65 range indicate GAS. Any fluorescence associated with a GAS zone indicates the presence of condensate. SEE i~IOTE BELOW. a) Values in the 15 - 20 range indicates gas rich in heavies, C4 and C5 ppms, and would most likely be associated with condensate. b) Values in the 20 - 50 range indicates gas rich in mid ranged hydrocarbons, C°_ and C3 ppms. o NOTE: o c) Values in the 50 - 65 range indicates gas rich in the lighter fraction, C1 ppms. C1/C2 ratios in the i0 - 20 range can indicate the presence of CONDENSATE or DISTIL~TE. Indications would be the presence of bright yellow or blue white fluorescence OR cut. (Condensate is a hydrocarbon that is a GAS under the temperatures and pressures of the reservoir but "condenses" to a LIQUID when it reaches the surface. It would compare to gasoline in appearance and physical characteristics and was in fact called "drip gas" in the early oilfield. C1/C2 ratios less than 2 and greater than 65 indicate NON-PRODUCIBLE HYDROCARBONS. Se a) A hydrocarbon with a value less than 2 indicates an OIL with a gravity so Iow (the oil is very thick) that it can't be produced. b) A hydrocarbon with a value greater than 65 indicates a light GAS, mostly C1, but the low permeability nature of the formation makes it non- producible. The slope of the line of all plotted ratios indicates if the zone will produce hydrocarbons only OR hydrocarbons and water. Line slope also provides some indication as to the formation permeability. a) An all positive slope_, up and to the right, indicate HYDROCARBONS ONLY. b) If _an, of the line segments have a negative slope, down and to the right, · .HYDROCARBONS AND SALTWA~;~R is indicaied. Obviously, the mud chlorides SHOULD increase but not necessarily. c) A steep line slope indicates reduced permeability AND the steeper the slope, the lower the permeability. Steep is a relative term BUT the dashed lines separating the GAS, OIL and NON-PRODUCIBLE areas of the graph are there for comparison. O11. plots whose line slope is somewhat steeper than the MIDDLE dashed line indicate Iow permeability. __ OIL plots whose line slope is .e..qual to or less than the MIDDLE dashed line indicate good permeability. -- GAS plots whose line slope is somewhat steer~er than the TOP dashed line indicate Iow p. ermeabilitv. -- GAS plots whose line slope is ec~ual to or less than the TOP dashed line indicate .good permenbilitv. DEPTH 1 41 3 OPERATION DRILLING FOOTAGE 1303 sr- y-sun DR,L,,NG SERV,CES L TGIAIG SYSTEI A DR~ I~)US~S IqC. COIV~ANY APPLIFT) DRILLING TECHNOLOGY MORNING REPORT NO. 1 DATE Mar 1098 TIME O0 01 OPERATOR BP EXPLORATION CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA LOGGING DATA BACKGROUND CONNECTION NONE TRIP FLOWLINE TEMP 76 AVG MAX AT GAS GAS DEPTH (units) (units) (feet) 10 1 7 1368 degrees F SURVEY DATA ~,.1137.45'DEV 16.83~ DEG AZ 43.1 DEG LITHOLOGY 20% CLAY - 10% SAND - 70% GRAVEL SAMPLE DEPTH 1480 TRIP CHLORIDES DRILL RATE f£/hr 135 LAG DOWN DP 295 CORRECTED "D" EXP. LAG OFF BOTTOM 2900 SHALE DENSITY g/cc NA EWR Res. 100+ PORE PRESSURE FRACTURE PRESSURE ECD FORMATION PRESSURE DATA CASING BOTTOM HOLE OPEN HOLE ~ psi ppg psi ppg ~ psi ~ ppg ~ psi ppg psi ~ ppg psi ppg psi ppg psi ppg psi ppg MUD DATA BIT DATA HYDRAULIC DATA 01:00 1 O-MAR-98 1 SPUD MUD TIME TYPE WEIGHT IN 10.2 FUNNEL VIS. 153 PV/YP ,22~36 G ELS ,13/59 pH 8.5 F ILT/CAKE APl ,14.2 / 3 HP-HT Pm Pf/Mf CHLORIDES ppm 700 CALCIUM ppm 40 OIL/WATER/S OLIDS DAILY/CUM. COST DP-CSG DP-HOLE DC-HOLE LENGTH - FT. BIT NO. TYPE MO250D IADC CODE W/MOTOR SIZE 12.25 JETS 1 2-12-12-12 DEPTH OUT INC ROT HRS. 9.5 FOOTAGE 1303 AVG ft/hr 137 GRADE INC HOLE DEV. 16.8 COST/FT 71 R P M 1 75 ITOT} WOB 2O-25 ANNULAR DATA VOLUME BBL$/FT. VELOCITY FT/MIN PUMPS SIZE inches CAPACITY gal/stk 2.96 PUMP RATE stks/min 95 FLOW RATE gal/min 562 PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 1. FIO00 2. FIO00 5.5xl 0 5.5xl 0 1725 2.96 95 psi at stk/min psi at stk/min CRIT-VEL FT/MIN ANN-VOL BBLS PIPE DATA DRILL STRING CASING: coND DP HWDP DC DEPTH 110 OD-inches 5.0 5.0 8.0 ,,, 20.0 ID-inches 4.276 ,3.0 2.875 19.12 CAP-bbls/ft .01776 .0087 .0080 .355 DIS P-bbls/ft .0075 .0181 .0542 .0192 LE NGTH-ft 731 456 226 80 W E I G HT-Ibs/ft 19. 5 49. 5 149 91.5 FEMARKS/[ND RECOMMENDATIONS "MW GPM JI=IS fi/mi = sec/std SPUD IN WELL @ 04:30 09-MAR-98. NB #1 RUN IN HOLE ON DIRECTIONAL ASSEMBLY WITH 1.5 DEG MUD MOTOR. START ANGLE BUILD @ 300'. DRILL TO 750' IN PREDOMINATELY GRAVEL FORMATION. SAND, GRAVEL AND CLAY BELOW THIS DEPTH. DRILL AHEAD WEIGHTING UP TO 10.2 IN ANTICIPATION OF PENETRATING HYDRATES. =! ,,, ADT · DEPTH 2842 (2695'I OPERATION CIRC. FOR S.T. FOOTAGE 1429 Sl:,, fy-sun DRILLING SERVICES LOGGING SYSTEt~,~ A D~ I~DUS~a~S ~qC, COMPANY APPUED DRILLING TECHNOLOGY MORNING REPORT NO. 2 DATE Mar 11 98 TIME O0 01 OPERATOR BP EXPLORATION CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA LOGGING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet) 2300 5725 1950 4753 2300 19 1498 74 degrees F SURVEY DATA ~,2756.9 DS 27.57 AZ 42.2 LITHOLOGY 60% CLAY - 20% SAND 20% GRAVEL ¢2830' SAMPLE DEPTH 2830 TRIP CHLORIDES DRILL RATE ft/hr 160 LAG DOWN DP 623 CORRECTED 'D" EXP. LAG OFF BOTTOM 5332 SHALE DENSITY g/cc EWR Res. NA FORMATION PRESSURE DATA PORE PRESSURE FRACTURE PRESSURE ECD CASING psi psi psi ~ PPg ,,, PPg PPg BOTTOM HOLE OPEN HOLE psi ~ ppg psi ppg psi ~ ppg ~ psi ppg psi ~ ppg psi ppg MUD DATA BIT DATA HYDRAULIC DATA TIME TYPE WEIGHT IN FUNNEL VIS. PV/YP GEL8 pH FILT/CAKE APl HP-HT Pm Pf/Mf CHLORIDES ppm CALCIUM ppm 01L/WATE R/$ OLID DAlLY/CUM. COST 01:00 11 -MAR-98 SPUD MUD 10.3+ 82 u BIT NO. TYPE MO250D IADC CODE W/MOTOR SIZE 12.25 JETS 12-12-12-12 DEPTH OUT INC ROT HRS. 17.5 FOOTAGE 2732 AVG fi/hr 156 GRADE INC HOLE DEV. 27.6 COST/FT 44 RPM 165 ITOT) WOB 20-30 5x 19.15 LENGTH - FT. DP-CSG 110 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .331 5X 12.25 ,, 8X 12.25 DP-HOLE 2505 .1215 DC-HOLE "227 .0837 PUMPS 1. FIO00 2. FIO00 SIZE inches 5.5xl 0 5.5xl 0 CAPACITY gal/stk 2.96 2.96 PUMP RATE stks/min 90 90 FLOW RATE gal/min 530 PRESSURE psi 1500 PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED I psi at , ,stk/min RATE 2 psi at stk/min CRIT-VEL FT/MIN ANN-VOL BBLS DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 ID-inches 4,276 3.0 2.875 CAP-bbls/ft .01776 .0087 .0080 DISP-bbls/ft .0075 .0181 .0542 LE N GTH-ft 2159 456 227 WEIGHT-Ibs/ft 19.5 49.5 149 PIPE DATA CASING: DEPTH COND 110 20.0 19.12 .355 .0192 8O 91.5 ~ AND RECOMMENDATIONS MW GPM JETS fi/mi = sec/std 'DRILL AHEAD BUILDING ANGLE TO 27.9 DEG. AT2619'. TOP OF FIRST HYDRATE ZONE ENCOUNTERED AT 1800' - APP1731' TVD WITH MAX GAS OF 4090 UNITS. WELL CHECKED FOR FLOW, NEGATIVE. CIRCULATED BOTTOMS UP. GAS DROPPED BELOW 2000 UNITS. DRILLED AHEAD TO ,, 1932'. CIRCULATED GAS OF 5000 UNITS. DRILLED TO 1963' AND CIRCULATED GAS OF 5731 UNITS. DRILLED AHEAD CIRCULATING GAS AT ON CONNECTIONS ATA REDUCED PUMP RATE. CONNECTION GASES ENCOUNTERED AFTER CONNECTION AT 2300' OF 4753 UNITS (1700 , OVER BACKGROUND). DRILLED AHEAD TO CASING POINT AT 2842.' TOOK MWD SURVEY AND CIRCULATED OUT FOR SHORT TRIP AT REPORT TIME. ,,,A DT DEPTH .2842 {2695 TVD) OPERATION NIPPLE DOWN FOOTAGE 0 , ,, OPERATOR BP EXPLORATION spy'-fy-sun D R . G S E R W C E S Z O GI/VG SYSTE/I/I!' A DI~r._SSER I',~USTI~S INC. COI~ANY ~ED DRILUNG TECHNOLOGY MORNING REPORT NO. ,3 DATE Mar 12~8 TIME O0 01 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA LOGGING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet) S.TRIP 4820 2842 73 degrees F SURVEY DATA ~2842 DS 27.6DEG AZ 42.2 LITHOLOGY 60% CLAY - 20% GRAVEL - 20% SAND SAMPLE DEPTH 2830 TRIP CHLORIDES DRILL RATE ft/hr 1 60 LAG DOWN DP 620 STKS CORRECTED "D" EXP. LAG OFF BOTTOM 1930STKS SHALE DENSITY g/cc NA EWR Res. NA CASING PORE PRESSURE psi FRACTURE PRESSURE , psi,, ECD psi FORMATION PRESSURE DATA BOTTOM HOLE OPEN HOLE ppg psi ppg psi Ppg psi ppg psi ppg psi ppg psi PPg PPg PPg MUD DATA BIT DATA TIME ,,13-FEB-98 BIT NO. 1 TYPE SPUD MUD TYPE MO250D WEIGHT IN 10.3 IADC CODE W/MOTOR FUNNEL VIS. 56 SIZE 12.25 PV/YP 22~6 JETS 12-12-12-12 GELS 3/10 DEPTH OUT 2842 pH 9.8 ROT HRS. 17.5 FILT/CAKE APl 11.0 2/32 HP-HT N FOOTAGE 2732 P m .60 AVG fi/hr 156 Pf/Uf .30/.90 GRADE 5 / 4 / BT CHLORIDES ppm 1000 HOLE DEV. 27.6 CALCIUM ppm 220 COST/FT 44 OIL/WATER/SOLIDS 0f90¢/10 RPM 165 (TOT) DAILY/CUM. COST WOB 20-30 LENGTH - FT. 5 x 19,15 DP-CSG 110 , , ANNULAR DATA VOLUME BBLS/FT. · 331 '5 X 12,25 DP-HOLE 2505 .1215 '~"X 12.25 DC-HOLE 227 .0837 VELOCITY FT/MIN HYDRAUUC DATA PUMPS 1. FIO00 2, FIO00 SIZE inches 5.5xl 0 5.5xl 0 CAPACITY gal/stk 2.96 2.96 PUMP RATE stks/min 90 90 FLOW RATE gal/rain 530 PRESSURE psi ~1500' PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED I psi at stk/min RATE 2 psi at s£k/min CRIT-VEL FT/MIN ANN-VOL BBLS PIPE DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2827 .,,., OD-inches 5.0 5.0 ,8.0 20.0 9.625 ID-inches 4.276 3;0 2.875 , 19.12 8.835 ,,, CAP-bbls/ft .01776 .0087 .0080 ,355 .0758 DISP-bbls/ft , ;0075 .0181 .0542 .0192 .0142 LE N GTH-ft 2159 456 227 8O 2797 WE IG HT-Ibs/ft 19.5 49.5 149 91.5 40# RE]t~E/f,S AND RECOMMENDATIONS MW GPM J~- IS ft;/mi = sec/std CBU. SHORT TRIP TO 683'. RIH. CBU. SHORT TRIP GAS OF 4820 UNITS AT 3400 STKS.. 4350 UNITS AT 4900 STKS, CIRC. UNTIL GAS"DROPPED BELOW 300 UNITS. DROPPED MULTI-SHOT SURVEY TOOL. POOH, RAN 9 5/8' CASING TO 2827'. PERFORMED TWO STAGE CEMENT JOB. NIPPLE DOWN HYDRIL STACK AT REPORT TIME. ADT DEPTH .,2862 {271 2 TVD) OPERATION CHG OVER MUD FOOTAGE 20 OPERATOR BP EXPLORATION sE 'ry-sun R--i G s E R Vl C E S Z O IiVG $Y$ TEt ,. A LI-IcSSER I~DUSTF~S ~IC. COMPANY APPU~ DRILLING TECHNOLOGY MORNING REPORT NO. .,4 DATE Mar 1398 TIME O0 01 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 LOGGING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet) 25 37 2848 NA 70 degrees F SURVEY DATA ~2842 DS 27.6 AZ 42.2 LITHOLOGY 60% CLAY - 20% GRAVEL - 20% SAND SAMPLE DEPTH 2830 TRIP CHLORIDES DRILL RATE fl,/hr 165 LAG DOWN DP 625 CORRECTED 'D' EXP. .75 LAG OFF BOTTOM 2000 SHALE DENSITY g/cc "NA EWR Res. NA PORE PRESSURE FRACTURE PRESSURE ECD CASING 1261 psi 9.0 2073 psi 14.7 psi FORMATION PRESSURE DATA BOTTOM HOLE OPEN HOLE ppg ,1268 psi 9.0 ppg psi ppg 2143 psi 14.7 ppg ~ psi PPg psi ppg psi ppg ppg ppg MUD DATA TIME 12-MAR-98 14:00 ! TYPE KCL-POLYMER WEIGHT IN 9,6 FUNNEL VIS. 59 PV/YP 2O / 24 GELS ,,6/8 pH 9.1 FILT/CAKE APl ,, 7,6 / 1 HP-HT N A Pm 0.15 Pr/Mr 0.06 / 0.25 CHLORIDES ppm 37000 CALCIUM ppm 160 OIL/WATER/SOLIDS 0 / 94 [ 6.1 DAILY/CUM. COST NA 8.835 DP-CSG 8.5 DP-HOLE LENGTH - FT. 2651 176 35 AVG ft/hr GRADE HOLE DEV. COST/FT RPM ,, WOB BIT DATA BIT NO. I 2 TYPE M 0250D DS7OFGNPV IADC CODE W/MOTOR PDC-MOTOR SIZE 12.25 8.5 JETS 12-12-12-12 6X12 DEPTH OUT 2842 ROT HRS. 17.5 .1 FOOTAGE 2732 20 15§ 167 5/4/BT 27.6 44 1234 ~ 65 ~'o'r) 1 oo 20-30 5 .a~INULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN ·0515 .0459 __ .0315 m~ .0259 HYI3:IAULIC DATA PUMPS 1. F 1000 2. FIO00 SIZE inches 5.5xl 0 5.5xl 0 CAPACITY gal/stk 2.96 2,96 PUMP RATE stks/min 60 60 FLOW RATE gal/min ,, PRESSURE psi 750 PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED I psi at, stk/min RATE 2 psi at stk/min GRIT-VEL FT/MIN ANN-VOL BBLS ii i 6.75 X 8.835 DC-CSG 6.75 X 8.5 DC-HOLE DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 I D-in ches 4.276 3.0 2.875 CAP-bbls/ft .01776 .0087 .0080 DISP-bbls/ft .0075 .0181 .0542 LE N GTH-ft 2193 456 211 WE I G HT-Ibs/ft 19.5 49.5 149 PIPE DATA CASING: DEPTH COND SURF 110 2827 ,,, 20. 0 9. 625 19.12 8.835 mil · 355 .0758 .0192 .0142 80 2827 91,5 4O# ~ AND RECOMMENDATIONS MB/------_ GPM Jr:: IS fi/mi = sec/$td NIPPLE DOWN HYDRIL. NIPPLE UP BOPS. TEST BOPS. RIH TO 1877'. CUT & SLIP DRILL LINE. RIH AND TAG CEMENT AT 2730'. CIRCULATE AND CONDITION MUD. TEST CASING TO 3000 PSI AND HOLD 30 MINUTES. DRILL CEMENT AND FLOAT EQUIPMENT FROM 2730' . DRILL SHOE AT 2827'. DRILL 8.5' HOLE FROM 2842' TO 2862'. CIRCULATE AND PREPARE FOR LEAKOFF TEST AT REPORT TIME. _ADT sp ,"y-sun DR,LUNG ERV,CES I OGG/NG S YS TE, t,t,> DEPTH 5044 (4645 TVD) OPERATION DRILLING A DI~SSER IXDUSTRES INC. COMPANY No. 5 DATE Mar 14 98 FOOTAGE 2182 ~PUED DRILLING TECHNOLOGY TIME O0 01 MORNING REPORT OPERATOR BP EXPLORATION WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U CONTRACTOR NABORS ALASKADRLG RIG NAME 18-E AREA NORTHWEST EILEEN START DATE Mar g98 LOC. CENTRAL NORTH SLOPE STATE ALASKA L(~ING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) ([eeo 425 3414 4625 8OO 2600 486O 4753 STG 4458 75 degrees F SURVEY DATA ~,4730.8 DS 28.26 AZ 44.8 LITHOLOGY 80% SILTSTONE, 20% SAND SAMPLE DEPTH 4960 TRIP CHLORIDES DRILL RATE ft/hr 185 LAG DOWN DP 1184 CORRECTED "D" EXP. 1.08 LAG OFF BOTTOM 4914 SHALE DENSITY g/cc "NA EWR Res. N A ,i PORE PRESSURE FRACTURE PRESSURE ECD FORMATION PRESSURE DATA CASING 1261 psi ,9.0 ppg 2073 psi 14.7 ppg 1446 psi 10.3 ppg BOTTOM HOLE OPEN HOLE 1268 psi ,,,9.0 ppg , psi ppg 3550 psi 14.4 ppg psi ppg 2488 psi 10.3 ppg psi ppg MUD DATA BIT DATA HYDRAUUC DATA ,1 4-MAR-98 00:30 BIT NO. 1 2 KCL-POLYMER TYPE M 0250D DS7OFGNPV IADC CODE W/MOTOR PDC-MOTOR SIZE 12.25 8.5 JETS 12-12-12-12 6X12 DEPTH OUT 2842 NA ROT HRS. 17.5 10 FOOTAGE 2732 2202 AVG ft/hr 156 220 GRADE 5 / 4 / BT HOLE DEV. 27.6 44.8 COST/FT 44 43 RPM 165 (TOT) 360 (TOT) W 0 B 20~30 10-15 , ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0515 TIME TYPE WEIGHT IN 9.6 FUNNEL VIS. 59 PV/YP ,,,12 / 27 GELS 7 / 13 pH 9.6 FILT/CAKE APl 7.0 / 1 HP-HT N A Pm 0.65 Pf/Mf 0.3 / 0.8 CHLORIDES ppm 28000 CALCIUM ppm 80 OIL/WATER/SOLIDS ,1 /94/5 DAILY/CUM· COST NA 5 x 8.835 DP-CSG PUMPS 1. F1000 SIZE inches 5.5xl 0 CAPACITY gal/stk 2.96 PUMP RATE stks/min 90 FLOW RATE gal/min PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED I RATE 2 5 X 8.5 DP-HOLE ,, ,,,,, 2. FIO00 5.5xl 0 2.96 90 ,,,, 535 1725 psi at stk/min psi at stk/min LENGTH- FT. CRIT-VEL FT/MIN ANN-VOL BBLS 2827 2006 ' ]'0459 0 .0315 211 6.75 X 8.835 DC-CSG 6.75 X 8.5 DC-HOLE · 0259 PIPE DATA CASING: COND SURF DEPTH 110 2827 20. 0 9. 625 19.12 8.835 DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 ID-inches 4.276 3.0 2.875 CAP-bbls/ft .01776 .0087 .0080 DISP-bbls/ft .0075 .0181 .0542 LE N GTH-ft 4377 456 211 WE IG HT-Ibs/ft 19.5 49.5 149 .355 .0758 .0192 .0142 80 2827 91.5 40# REMARKS AND RECOMMENDATIONS MW, GPM JI:IS ' fi/mi = sec/std PERFORMED LEAK-OFF TEST W/ EQ. MW 14.7 PPG. CHANGED OVER MUD TO KCL-POLYMER. DRILLED AHEAD FROM 2862' TO 4458'. SHORT TRIP TO 2827'. ENCOUNTERED TIGHT SPOT RUNNING IN AT 3078'. PICKED UP KELLY AND WORKED TIGHT SPOT. CONTINUED TO I~OTTOM. DRILLED FROM 4458' TO 5044'. =, _ ADT DEPTH 6790t6233 TVD) OPERATION DRILLING FOOTAGE 1 746 OPERATOR BP EXPLORATION sF ny-sun 'R,LL,NG SERWCES Z TGIAIG SYSTEI . A m.,s s ~U~ DRI~NG ~CHNOL~Y MORNING REPORT NO. 6 DATE Mar 1598 TIME O0 01 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 LOGGING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX GAS GAS (units) (uni£s) 550 660 ,, 11 O0 2050 2281 AT DEPTH (feet) 5370 5885 STG 5979 degrees F SURVEY DATA 6783.2' MD 6231.4' TVD 13.5 DEG. 35.6 AZIM LITHOLOGY 20%VOLC. TUFF. 80% SHALE SAMPLE DEPTH 6730 TRIP CHLORIDES NA DRILL RATE ft/hr 150 LAG DOWN DP 1625 CORRECTED "D" EXP. .1.04 LAG OFF BOTTOM 5255 SHALE DENSITY g/cc NA EWR Res. NA CASING PORE PRESSURE 1261 psi ,.9.0 ppg FRACTURE PRESSURE 2073 psi ,,,,14.7 ppg ECD 1544 psi 10.5 ppg FORMATION PRESSURE DATA BOTTOM HOLE OPEN HOLE 3112 psi 9.6 ppg psi . ppg 4765 psi 14.7 ppg psi ., ppg 3403 psi 10.5 ppg psi ppg MUD DATA TIME 1 5;MAR-98 00:00 TYPE KCL-POLYMER WEIGHT IN 9.7 FUNNEL VIS. 64 PV/YP 19/24 G ELS 6/16 pH 8.8 FILT/CAKE APl 5.5/1 H P-HT N A Pm 0.35 Pr/Mr O. 10/'O. 90 CHLORIDES ppm 30000 CALCIUM ppm 100 OIL/WATER/SOLIDS 1.0 / 93.0 ,/4.3 DAILY/CUM. COST NA ,, BIT NO. TYPE IADC CODE SIZE JETS DEPTH OUT ROT HRS. FOOTAGE AVG ft/hr GRADE HOLE DEV. COST/FT RPM WOB 5 x 8.835 DP-CSG LENGTH - FT. 2827 5 X 8.5 DP-HOLE ' 3752 6.75 X 8.835 DC-CSG 0 6.75 X 8.5 DC-HOLE 211 BIT DATA MO25OD W/MOTOR 12.25 1 2-12-12-12 2842 17.5 2732 156 DS7OFGNPV PDC-MOTOR 27.6 44 8.5 6X12 NA 24.4 3948 162 5/4/BT INC 13.5 1 65 (TOT) 20-30 45 330 {TOT) ! 10-15 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN · 0515 HYDRAUUC DATA PUMPS 1. FIO00 2. FIO00 SIZE inches 5.5xl 0 5.5xl 0 CAPACITY gal/stk 2.96 2.96 PUMP RATE stks/min 90 90 FLOW RATE gal/min 535 PRESSURE psi 1900-21 O0 PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED I psi at stk/min RATE 2 psi at stk/min CRIT-VEL FT/MIN ANN-VOL BBLS .0459 .0315 .0259 DP HWDP OD-inches 5.0 5.0 ID-inches 4.276 3.0 CAP-bbls/ft .01776 .0087 DISP-bbls/ft .0075 .0181 LENGTH-ft 6123 456 WEIGHT-Ibs/ft 19.5 49.5 DRILL STRING DC 2.875 .0080 .0542 211 149 PIPE DATA CASING: COND SURF DEPTH 110 2827 20.0 9.625 19.12 8.835 .355 .0758 ..... .0192 .0142 80 2827 91.5 40# ~ AND RECOMMENDATIONS MW GPM J~- iS fi/mi = sec/std DRILLED FROM 5044' TO 5979', PUMPED SWEEP, CIRCULATE AND CONDITION HOLE. SHORT TRIP TO 4500'. RAN IN HOLE TO 5280'. HOLE SWABBED SLIGHTLY. RAN IN HOLE TO BOTTOM AND DRILLED TO 6790'. DRILLING AHEAD TO CORE POINT AT REPORT TIME. ADI DEPTH 7062 {6505 TVO) OPERATION CIRC. & COND. FOOTAGE 272 OPERATOR BP EXPLORATION sE -ry-sun SERV,CES ZOHH//VH SYSTE/I,,. A DF~S~]~ I~DUS'[RES ~c. ~ANY APPUFD~ DRILLING TECHNOLOGY MORNING REPORT NO. 7 DATE Mar 1698 TIME O0 01 WELL NAME NW EILEEN#1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 L~ING DATA AVG MAX AT GAS GAS DEPTH (units) (units) (feet) BACKGROUND 800 4131 7050 .. CONNECTION 2000 ,,2725 6914 TRIP 1000 5193 7062ST FLOWLINE TEMP 74 degrees F SURVEY DATA .6989.4' MD 6433.5' TVD 9.59 DEG.r AZIM 45.3 LITHOLOGY 40% SAND. 6O% SHALE SAMPLE DEPTH 7060' TRIP CHLORIDES NA DRILL RATE [t/hr 110 LAG DOWN DP 1672 CORRECTED "D" EXP. .87 LAG OFF BOTTOM 5255 SHALE DENSITY g/cc NA EWR Res. NA CASING PORE PRESSURE 7261 psi 9.0 FRACTURE PRESSURE 2073 psi 14.7 , ECD 1646 psi 10.5 FORMA~ PRESSURE DATA BOTTOM HOLE OPEN HOLE ppg 3450 psi 10.2 ppg psi . ppg 5345 psi 15.8 ppg psi ppg 3992 psi 11.8 ppg psi ppg ft ppg ft PPg ft MUD DATA BIT DATA HYDRAULIC DATA 1 6-MAR-98 00:00 I 2 6% KCL - CORING FLUID TIME BIT NO. TYPE TYPE WEIGHT IN 11.3 IADC CODE FUNNEL VIS. 122 SIZE PV/YP ,,36~33 JETS GELS ~/14 DEPTH OUT pH 8.6 FILT/CAKE APl NAr1 ROT HRS. HP-HT NA FOOTAGE P m 1 AVG fi/hr Pf/Mf 0/.2 GRADE CHLORIDES ppm 30000 HOLE DEV. CALCIUM ppm 200 COST/FT OIL/WATER/SOLIDS , 1.0/88/11 RPM DAILY/CUM. COST NA WOB LENGTH - FT. 5 x 8.835 DP-CSG 2827 5 X 8.5 DP-HOLE 4024 __ 6.75 X 8.835 DC-CSG 0 6.75 X 8.5 DC-HOLE 211 .0259 DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 ID-inches 4,276 3.0 2,875 CAP-bbls/ft i~1776 .0087 .0080 DISP-bbls/ft id~)75 .0181 .0542 LENGTH-ft 6395 456 211 WE I G HT-Ibs/ft 19.5 49.5 149 MO250D W/MOTOR DS7OFGNPV PDC-MOTOR 12.25 8.5 12-12-12-12 6X12 2842 NA 17.5 29.1 2732 4220 156 145 5 / 4 / BT INC 27.6 19,59 44 48 1 65 fTOTt 20-30 330 (TOT) 10-15 ANNUlaR DATA VOLUME BBLS/FT. VELOCITY FT/MIN · 0515 m .0459 .0315 PIPE DATA PUMPS 1. FIO00 SIZE inches 5.5xl 0 CAPACITY gal/stk 2.96 PUMP RATE stks/min 90 FLOW RATE gal/rain PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CRIT-VEL FT/MIN CASING: COND SURF DEPTH 110 2827 2. FIO00 5.5xl 0 2.96 9O 535 21 5O psi at stk/min psi at stk/min ANN-VOL BBLS 20.0 9.625 19.12 8,835 . , .355 .0758 .0192 .0142 80 2827 91.5 40# MW GPM Jb~S I-~MARKS AND RECOMMENDATIONS fi/mi = sec/std DRILLED FROM 6790' TO 7062' WHILE INCREASING MUD WT TO 11.3. HIGH RESISTIVITY SPIKE OBSERVED FROM 7020'. PICK ED UP OFF BOTTOM AND CIRCULATED OUT SAND WITH OIL SHOW, SHORT TRIPPED TO 4853' WITHOUT PROBLEM, SHORT TRIP GAS OF 5195 UNITS. CIRCULATED AND CONDITIONED MUD WHILE SWAPPING MUD SYSTEM AND HOLE WITH CORING FLUID. SHORT TRIPPED TO 5973', RAN IN HOLE AND CIRCULATED OUT WITH SHORT TRIP GAS OF 1093 UNITS. PULLED TEN STANDS, OBSERVED WELL FLOWING, RAN IN HOLE SLOWLY. CIRCULATED OUT 910 UNITS SHORT TRIP GAS. CIRCULATING AND CONDITIONING MUD SYSTEM FROM 11.0 PPG TO 11.3 PPG AT REPORT TIME. gDT DEPTH OPERATION FOOTAGE 7062 t6505 TVDt WASH & REAM 0 sp, 'y-sun DR LL,,G SERV,CES ZO TGING SYSTE/ ,... A DPGS~ER I',DUSTF~S iNC. COI~ANY APPUED DRILUNG TECHNOLOGY MORNING REPORT NO. 8 DATE Mar 1798 TIME O0 01 OPERATOR CONTRACTOR START DATE BP EXPLORATION NABORS ALASKA DRLG Mar 9 98 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA LOGGING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (foeO NA NA OPEN NA NA HOLE 3000 4693 2970' 86 degrees F SURVEY DATA 6989.4' MD 6433.5' TVD 9.59 DEG.r AZIM 45.3 LITHOLOGY 40% SAND, 60% SHALE SAMPLE DEPTH 7060' TRIP CHLORIDES NA DRILL RATE fi/hr 110 LAG DOWN DP 1672 CORRECTED "D" EXP, .87 LAG OFF BOTTOM 5255 SHALE DENSITY g/cc NA EWR Res, NA PORE PRESSURE FRACTURE PRESSURE LCD CASING 1261 psi 9.0 2073 psi 14.7 1646 psi 10.5 FORMA~ON PRESSURE DATA BOTTOM HOLE OPEN HOLE ppg 3450 psi 10.2 ppg psi ppg 5345 psi 15.8 ppg psi ppg 3992 psi 11.8 ppg psi ppg ppg ppg MUD DATA BIT DATA HYDRAULIC DATA TIME TYPE WEIGHT IN 11.4 FUNNEL VIS. 150 PV/YP ,,44/39 G ELS 8/17 pH 8.5 FILT/CAKE APl 4.3/1 H P-HT 8.2 P m 1.95 Pf/Mf 0/.2 CHLORIDES ppm 32000 CALCIUM ppm 260 OIL/WATER/SOLIDS 1.0 / 86 / 13 DAILY/CUM. COST NA 1 7-MAR-98 00:00 6% KCL - CORING FLUID 5 x 8.835 DP-CSG 5 X 8.5 DP-HOLE LENGTH - FT. 2827 4033 0 202 ROT HRS. FOOTAGE AVG ft/hr GRADE HOLE DEV. COST/FT RPM WOB BIT NO. 2 TYPE DS7OFGNPV IADC CODE PDC-MOTOR SIZE 8.5 JETS 6X12 DEPTH OUT 7062 29.1 4220 145 5/4/BT 19.59 48 330 ~OT) 10-15 - ANNULAR DATA VOLUME BBLS/FT. .0515 .0459 .0315 .0259 3 ARC 412C3 CORE BIT 1 8.5 .77 TFA 7062 0 0 19.59 VELOCITY FT/MIN PUMPS 1. Fl000 2. Fl000 SIZE inches 5.5xl 0 5.5xl 0 CAPACITY gal/stk 2.96 2.96 PUMP RATE stks/min 50 50 FLOW RATE gal/min 300TOT PRESSURE psi 960 PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED I psi at stk/min RATE 2 psi at stk/min CRIT-VEL FT/MIN ANN-VOL BBLS 6.75 X 8.835 DC-CSG iii 6.75 X 8.5 DC-HOLE DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 ID-inches 4.276 3.0 2.875 CAP-b bls/ft .01776 .0087 .0080 DISP-bbls/ft .0075 .0181 .0542 LE N GTH-ft 6403 457 202 WE IG HT-Ibs/ft 19.5 49.5 149 PIPE DATA CORE BHA CASING: COND SURF DEPTH 110 2827 REMARKS AND RECOMMENDATIONS 20.0 9. 625 19.12 8.835 .355 .0758 .0192 .0142 80 2827 91.5 40# MW GPM JETS fi/mi = sec/std CIRCULATED AND CONDITIONED CORING FLUID TOll,3PPG. PULLED OUT OF HOLE TOBHA. LAYED DOWN MWD, MUD MOTOR, STABILIZER AND BIT #2. PICKED UP CORING ASSEMBLY AND RAN IN HOLE. ENCOUNTERED TIGHT SPOT AT 2934'. COULD NOT WORK THROUGH. PULLED OUT OF HOLE AND PICKED UP HOLE OPENER. RAN IN HOLE TO 2879'. REAMED HOLE FROM 2879' TO 2950'. CIRCULATED HOLE CLEAN WITH A MAX GAS OF 4693 UNITS. ,,, _ADT DEPTH 7062 {6505 TVD) OPERATION RIH FOR CORE 1 FOOTAGE 0 OPERATOR BP EXPLORATION sE -ry-sun D RI---LL,NG SERVICES A DFESSER I~)USTR~S [NC. COMPANY APPUED DRILUNG TECHNOLOGY MORNING REPORT NO. 9 DATE Mar 18 98, TIME O0 01 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA LOGGING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet) NA NA NA NA 86 degrees F SURVEY DATA 6989.4' MD 6433.5' TVD 9.59 DEG.I AZIM 45.3 LITHOLOGY 40% SAND, 60% SHALE SAMPLE DEPTH 7060' TRIP CHLORIDES NA DRILL RATE ft/hr 110 LAG DOWN DP 1672 CORRECTED "D" EXP. .87 LAG OFF BOTTOM 5255 SHALE DENSITY g/cc NA EWR Res. NA PORE PRESSURE FRACTURE PRESSURE ECD CASING 1261 psi 9.0 2073 psi 14.7 1646 psi 10.5 FORMATION PRESSURE DATA BOTTOM HOLE OPEN HOLE ppg 3450 psi 10.2 ppg psi ppg 5345 psi 15.8 ppg psi ppg 3992 psi 11.8 ppg psi PPg PPg PPg MUD DATA TIME TYPE WEIGHT IN 11.4 FUNNEL VIS. 220 PV/YP ,48/37 G ELS 8/19 pH 8.2 FILT/CAKE APl ,,,2.4/2 HP-HT 7.0 Pm 1.3 Pf/Mf Of.3 CHLORIDES ppm 31000 CALCIUM ppm 240 OIL/WATER/SOLIDS ,,, 1.0 / 86 / 13 DAILY/CUM. COST NA 17-MAR-98 00:00 6% KCL - CORING FLUID BIT DATA BIT NO. 2 3 TYPE DS7OFGNPV ARC 412C3 IADC CODE PDC-MOTOR CORE BIT1 SIZE 8.5 8.5 JETS 6Xl 2 DEPTH OUT 7062 .77 TFA 7062 29.1 0 0 422O 145 5/4/BT 19.59 48 330 (TOT) 10-15 ROT HRS. FOOTAGE AVG ft/hr GRADE HOLE DEV. COST/FT RPM WOB 19.59 HYDRAUUC DATA ANNULAR DATA PUMPS 1. F 1000 SIZE inches 5.5xl 0 CAPACITY gal/stk 2.96 PUMP RATE stks/min 65 FLOW RATE gal/min PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 LENGTH - FT. VOLUME BBLS/FT. VELOCITY FT/MIN CRIT-VEL FT/MIN 5 x 8.835 DP-CSG 2827 .0515 2. FIO00 5.5x10 2.96 ,, 70 400TOT 850-940 psi at stl~fmin psi at stk/min ANN-VOL BBLS 5 X 8;5 DP-HOLE 4033 .0459 _ 6.75 X 8.835 DC-CSG 0 .0315 6.75 X 8.5 DC-HOLE 202 .0259 PIPE DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2827 OD-inches 5.0 5.0 8.0 20.0 9.625 ID-inches 4.276 3,0 2.875 19.12 8.835 CAP-bbls/ft .01776 .0087 .0080 .355 .0758 ,, DIS P-bbls/ft .0075 .0181 .0542 .0192 .0142 L E N G TH-ft 6403 457 202 80 2827 WE IG HT-Ibs/ft 19.5 49.5 149 91.5 40# REMARKS AND RECOMMENDATIONS ' "~W GPM JIllS E/mi = sec/std ,, REAMED TIGHT SPOTS WITH HOLE OPENER FROM 2950' TO 3076' WITH A MAX GAS OF 4693 UNITS. RAN IN HOLE TO 4310', HIT A TIGHT SPOT. HOLE OPENER PLUGGED OFF AND COULD NOT CIRCULATE. PULLED OUT OF HOLE AND UNPLUGGED HOLE OPENER. RAN IN HOLE TO SHOE. BROKE CIRCULATION. WASHED FROM 4289' TO 4382'. 'RAN IN HOLE TO 6956 AND WASHED TO BOTTOM WITH TRIP GAS OF 2140 UNITS. . ,. CIRCULATED AND CONDITIONED MUD. PULLED OUT OF' HOLE. PICKED UP CORE BARREL AND RAN IN HOLE TO SHOE. BROKE CIRCULATION AT SHOE. RAN IN HOLE TO 3262' AND WASHED THROUGH TIGHT SPOTS W/MAX GAS 179 UNITS.. RAN IN HOLE TO 4022'. WASHED THROUGH TIGHT SPOTS. RAN STANDS FROM DERRICK FROM 4125' TO 4186'. WASH TIGHT SPOTS AT REPORT TIME. ADT DEPTH OPERATION FOOTAGE 711 5 {6558 TVD) RIH FOR CORE 2 53 sp"-ry-sun DR=~:'L .~G SERVICES LOGGING SYSTEI~, A DFESS~R IXDUSTRES ~qC. COMP~ APPUED DRILLING TECHNOLOGY MORNING REPORT NO. 10 DATE Mar 19 98 TIME O0 01 OPERATOR CONTRACTOR START DATE BP EXPLORATION NABORS ALASKA DRLG Mar 9 98 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA L~ING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet) 290 442 7088 207 250 ST 7062 92 degrees F SURVEY DATA 6989.4' MD 6433.5' TVD 9.59 DEG.~ AZIM 45.3 LITHOLOGY 10% SAND. 10% SILTSTONE. 90% CLAY SAMPLE DEPTH 7115' TRIP CHLORIDES NA DRILL RATE ft/hr 20 LAG DOWN DP 1695 CORRECTED "D" EXP. 1.51 LAG OFF BOTTOM 5290 SHALE DENSITY g/cc NA EWR Res. NA PORE PRESSURE FRACTURE PRESSURE ECD FORMATION PRESSURE DATA CASING BOTTOM HOLE OPEN HOLE 1261 psi g.0 ppg 3450 psi 10.2 ppg psi ppg 2073 psi 14.7 ppg .,5345 psi 15.8 ppg ~ psi ppg 1646 psi 10.5 ppg 3992 psi 11.8 ppg psi ppg MUD DATA BIT DATA HYDRAUUC DATA 19-MAR-98 00:00 4 TIME TYPE WEIGHT IN FUNNEL VIS. PV/YP GELS pH FILT/CAKE APl HP-HT Pm Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST BIT NO. 3 6% KCL - CORING FLUID TYPE ARC 412C3 11.5 IADC CODE CORE BIT1 163 SIZE 8.5 44 ~ 39 JETS .77 TFA 8/18 DEPTH OUT 7115 8.2 ROT HRS. 2.2 , ,2..4/1 FOOTAGE 53 7.0 1.4 AVG ft/hr 24.1 0f.4 GRADE 31000 HOLE DEV. 19.59 280 COST/FT 898 1.0 f' 84 / 15 RPM 235 NA WOB 5-10 5 x 8.835 DP-CSG '5 X 8.5 DP-HOLE ARC 425 CORE BIT 2 8.5 .75 TFA INC ANNULAR DATA LENGTH ~ FT. VOLUME BBL$/FT. VELOCITY FT/MIN 2827 .0515 4057 .0459 0 '10315 231 .0259 PUMPS 1. FIO00 2. FIO00 SIZE inches 5.5xl 0 5.5xl 0 CAPACITY gal/stk 2.96 2.96 PUMP RATE stks/min 49 49 FLOW RATE gal/min 288 PRESSURE psi 1120 - 1200 PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED I psi at stk/min RATE 2 psi at stk/min CRIT-VEL FT/MIN ANN-VOL BBLS 6.75 X 8.835 DC-CSG "'~.'75 X 8.5 DC-HOLE DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 ID-inches 4.276 3.0 2.875 CAP-bbls/ft .01776 .0087 .0080 DISP-bbls/ft .0075 .0181 .0542 L E N G TH-ft 6427 457 231 W E I G HT-Ibs/ft 19.5 49.5 149 PIPE DATA CASING: COND SURF DEPTH 110 2827 20.0 9.625 19.12 8.835 .355 .0758 .0192 .0142 80 2827 91.5 40# ~ AND RECOMMENDATIONS MW GPM JETS ft/mi = sec/std 'RAN IN HOLE, TAGGED BOTTOM, CIRCULATED OUT WITH TRIP GAS OF 207 UNITS. CIRCULATED AND CONDITIONED MUD. SHORT TRIPPED TO 6085', NO PROBLEMS. SHORT TRIP GAS OF 108 UNITS. DROPPED BALL AND CORED FROM 7062' TO 7115' WITH MAX GAS OF 442 UNITS. PULLED OUT OF HOLE WITH CORE #1 TEN STANDS. HOLE DIDN'T TAKE ENOUGH FLUID. RAN IN HOLE AND CIRCULATED BO-i-roMs UP WITH SHORT TRIP GAS OF 250 UNITS. PULLED OUT OF HOLE AND LAYED DOWN CORE #1, MADE UP CORE BARREL ~'2. RUNNING IN HO~_E AT REPORT TIME. ADT DEPTH 71 34 (6570 TVD) OPERATION M/U DIR BHA FOOTAGE 19 OPERATOR BP EXPLORATION s --ry-sun .4 G s E R v,c E s L O TGI/VG SYSTE , A DFE_~ I'~DUS'I'I:~S ~C. COMPANY APPUED DRILLING TECHNOLOGY MORNING REPORT NO. 11 DATE Mar 2098 TIME O0 01 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA L~ING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feeO 25 57 7119' 367 7115' 82 degrees F SURVEY DATA 6989.4' MD 6433.5' TVD 9.59 DEG.T AZIM 45.3 LITHOLOGY 10% SAND, 10% SILTSTONE. 90% CLAY SAMPLE DEPTH =.7,130' TRIP CHLORIDES NA DRILL RATE f£/hr 2.5 LAG DOWN DP 1698 CORRECTED "D" EXP. .1,.43 LAG OFF BOTTOM 5296 SHALE DENSITY g/cc NA EWR Res. NA CASING PORE PRESSURE 1261 psi 9.0 FRACTURE PRESSURE 2073 psi 14.7 ECD 1646 psi 10.5 FORMATION PRESSURE DATA BOTTOM HOLE OPEN HOLE , ppg 3488 psi 10.2 ppg psi , ppg ppg 5540 psi 16.2 ppg psi ppg ppg 4035 psi 11.8 ppg psi ppg MUD DATA BIT DATA HYDRAUUC DATA 1 9-MAR-98 00:00 BIT NO. 4 RR 2 6% KCL - CORING FLUID TYPE ARC 425 DSTOFGNPV TIME TYPE WEIGHT IN FUNNEL VIS. PV/YP GELS pH FILT/CAKE APl HP-HT Pm Pr/Mr CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST 11.3 154 45 f 39 8/18 8.2 2.3/2 7.0 1.0 Of. 25 30000 IADC CODE CORE BIT2 PDC-MOTOR SIZE 8.5 8.5 JETS . 75 TFA 6X12 .66 TFA .,,, DEPTH OUT 7134 INC ROT HRS. 7.5 FOOTAGE 19 AVG fi/hr 12.5 GRADE HOLE DEV. 19.59 COST/FT 3310 RPM 8O WOB 10 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0515 4082 .0459 260 1.0/86/13 NA 5 x 8.835 DP-CSG LENGTH - FT. 2827 5 X 8.5 DP-HOLE PUMPS 1. F1000 SIZE inches 5.5xl 0 CAPACITY gal/stk 2.96 PUMP RATE stks/min 50 FLOW RATE gal/min PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 2. FIO00 5.5xl 0 2.96 ,, 48 291 1250 psi at stk/min psi at stk/min CRIT-VEL FT/MIN ANN-VOL BBLS ,, 6.75 X 8.835 DC-CSG 0 .0315 .0259 6.75 X 8.5 DC-HOLE 225 PIPE DATA DRILL STRING CASING: DP HWDP DC DEPTH OD-inches 5.0 . ,5.0 8.0 20.0 ID-inches . ,4.276 3.0 2.875 19.12 CAP-bbls/ft .01776 .0087 .0080 , .355 , , DISP-bbls/ft .0075 .0181 .0542 .0192 LE N GTH-ft 6361 518 255 80 W E IG HT-Ibs/ft 19.5 49.5 149 91.5 MW GPM JEfS RF_MAi~(S AND RECOMMENDATIONS COND SURF 110 2827 9.625 8. 835 .0758 .0142 2827 40# fi/mi = sec/std · RAN IN HOLE TO SHOE. BROKE CIRCULATION. RAN IN HOLE TO BOTTOM AT 7115'. CIRCULATED AND CONDITIONED MUD. TRIP GAS OF 367 UNITS. CONTINUED CIRCULATING ONE ADDITIONAL BOTTOMS UP. CLOT CORE FROM 711 5' TO 7134'. OBSERVED WELL AND SHUT IN FOR 30 MIN WITH NO PRESSURE. CIRCULATED OUT AGAIN WITH A MAX GAS 'OF 347 UNITS COMING FROM HYDRATE ZONE AT APPROX. 2950'. PULLED OUT OF HOLE AND LAYED DOWN CORE #2. PREPARING TO RUN IN HOLE WITH MUD MOTOR AND PDC BIT AT REPORT TIMId. ADT sr' -wy-sun SERWCE$ LOGGING SYSTE& DEPTH 7511' (6946' TVD) OPERATION DRILLING ADFESSERN3US~SINC. COMPANY NO. 12 DATE 'Mar 21 98 .FOOTAGE 377 APPUED DRILLING TECHNOLOGY TIME O0 01 MORNING REPORT OPERATOR BP EXPLORATION WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U CONTRACTOR NABORS ALASKADRLG RIG NAME 18-E AREA NORTHWEST EILEEN START DATE Mar 998 LOC. CENTRAL NORTH SLOPE STATE ALASKA L~ING DATA AVG MAX AT SURVEY DATA 7353' MD 6791' TVD 9.42 DEG.~ AZIM 42.8 GAS GAS DEPTH LITHOLOGY 100% SILTSTONE (units) (units) (feet) SAMPLE DEPTH 7500 BACKGROUND 25 630 7175 TRIP CHLORIDES NA DRILL RATE ft/hr 6.0 CONNECTION 405 87O 7426 LAG DOWN DP 1786 CORRECTED 'D" EXP. 1.35 TRIP 657 7115 LAG OFF BOTTOM 5481 SHALE DENSITY g/cc NA FLOWLINE TEMP ,100 degrees F EWR Res. NA FORMA~ PRESSURE DATA CASING BOTTOM HOLE OPEN HOLE PORE PRESSURE 1261 psi 9.0 ppg 3503 psi ,9.7 ppg , psi , ppg ft FRACTURE PRESSURE .2073 psi .14.7 ppg 5851 psi 16.2 ppg psi ppg ft ECD 1882 psi 12.8 ppg 4623 psi 12.8 ppg psi ppg ft MUD DATA BIT DATA :TIME TYPE WEIGHT IN 11.3 ,,, FUNNEL VIS. 89 PV/YP 34/32 GELS ,,,6 ~ 13 pH 9.1 FILT/CAKE APl ,,,3.0/1 HP-HT 7.4 Pm 1.4 Pf/Mf 0.1 /.5 CHLORIDES ppm 30500 CALCIUM ppm 140 OIL/WATER/SOLIDS 1.0 / 85 / 14 DAILY/CUM. COST NA 5 x 8.835 DP-CSG 5 X 8.5 DP-HOLE 6.75 X 8.835 DC-CSG 6.75 X 8.5 DC-HOLE 21-MAR-98 00:00 6% KCL - CORING FLUID LENGTH - FT. 2827 4429 BIT NO. 4 TYPE ARC 425 IADC CODE CORE BIT2 SIZE 8.5 JETS .75 TFA DEPTH OUT 7134 RR2 DS7OFGNPV PDC-MOTOR 8.5 6X12 .66 TFA INC HYDRAUUC DATA PUMPS 1. FIO00 2. FIO00 SIZE inches 5.5xl 0 5.5xl 0 ! CAPACITY gal/stk 2.96 2.96 PUMP RATE stks/min 90 90 FLOW RATE gal/rain 534 TOTAL ROT HRS. 7.5 FOOTAGE 19 AVG fi/hr 12.5 GRADE HOLE DEV. 19.59 COST/FT 3310 RPM 8O WOB 10 8.1 377 25.8 9.42 211 183 (TOT) 18 ANNULAR DATA PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 2350-2450 psi at stk/min psi at stk/min ! "'225 VOLUME BBLS/FT. .0515 .0459 '.'~315 .0259 DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 ID-inches 4.276 3.0 2.875 CAP-bbls/ft .01776 .0087 .0080 DISP-bbls/ft .0075 .0181 .0542 LE N GTH-ft 6768 518 225 W E I G HT-Ibs/ft 19.5 49.5 149 PIPE DATA VELOCITY FT/MIN CASING: DEPTH CRIT-VEL FT/MIN ANN-VOL BBLS 146 210 O. 6 COND SURF 110 2827 20.0 9.625 19.12 8.835 .355 .0758 .0192 .0142 80 2827 91.5 40# ~ AND RECOMMENDATIONS " MW GPM JP_.~S fi/mi -- sec/std ,, ,PICKED UP NEW BHA AND RAN IN HOLE. SURFACE TESTED MUD MOTOR AND MWD. RAN IN TO SHOE. CIRCULATED BOTTOMS UP WITH 1165 UNITS FROM HYDRATE ZONE AT APPROXIMATELY 2950'. TESTED BOPS AT SHOE. RAN IN HOLE TO 7050' AND MAD PASSED W/MWD TO 7134'. TRIP GAS OF 657 UNITS FROM SHALLOW HYDRATE ZONE. 529 UNITS FROM KUPARUK C. DRILLED FROM 71 34' TO 7511' AT REPORT TIME. __ ADT DEPTH OPERATION FOOTAGE sP =rry-sun DRILLING SERVICES LOGGIAIG SYSTEMS 7583' {7017' TVD} A DEE~ ~TI:~S IqC. C~ NO. 13 E-LOG DATE Mar2298 72 ~U~ DRI~NG ~CHNOL~Y TIME O0 01 MORNING REPORT OPERATOR CONTRACTOR START DATE BP EXPLORATION WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U NABORS ALASKA DRLG RIG NAME 18-E AREA NORTHWEST EILEEN Mar 998 LOC. CENTRAL NORTH SLOPE STATE ALASKA L~ING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet.) 25 42 7575 4O7 11 44 7552 1 027 STG 7115 SURVEY DATA 7583' MD 7019' TVD 8.74 DEG.T AZIM 41.6 LITHOLOGY 90% SILTSTONE lO%SANDSTONE SAMPLE DEPTH 7583 TRIP CHLORIDES NA DRILL RATE ft/hr 6. O LAG DOWN DP 1795 CORRECTED 'D" EXP. 1.35 LAG OFF BOTTOM 5495 SHALE DENSITY g/cc NA 100 degrees F EWR Res. ,NA FORMATION PRESSURE DATA PORE PRESSURE FRACTURE PRESSURE ECD CASING BOTTOM HOLE 1261 psi 9.0 ppg 3510 psi 9.7 ppg 2073 psi 14.7 ppg 5860 psi 16.2 ppg 1882 psi 12.8 ppg 4630 psi 12.8 ppg OPEN HOLE psi ppg ft psi ppg ft psi ppg ft MUD DATA BIT DATA HYDRAULIC DATA 4 RR2 TIME TYPE WEIGHT IN 11.3 FUNNEL VIS. 89 PV/YP 34 ~32 GELS 6 / 13 pH 9.1 FILT/CAKE APl ,3.0 ~'1 HP-HT 7.4 Pm 1.4 Pf/Mf 0.1 ,/.5 CHLORIDES ppm 30500 CALCIUM ppm 140 OIL/WATER/SOLIDS 1.0 / 85 ~ 14 DAILY/CUM. COST NA 21-MAR-98 00:00 6% KCL - CORING FLUID LENGTH - FT. 5 x 8.835 DP-CSG 2827 BIT NO. TYPE IADC CODE SIZE JETS DEPTH OUT ROT HRS. FOOTAGE AVG ft/hr GRADE HOLE DEV. COST/FT RPM WOB ARC 425 CORE BIT 2 DS7OFGNPV PDC-MOTOR 8.5 8.5 · 75 TFA 6X12 .66 TFA 7134 INC 7.5 17.4 19 449 12.5 25.8 19.59 8.74 3310 254 80 lO 183 {TOT) 15-25 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN · 0515 5 X 8.5 DP-HOLE 4531 .0459 ' '6.75 X 8.835 D C-CSG 0 .0315 6.75 X 8.5 DC-HOLE 225 .0259 PUMPS 1. F1000 SIZE inches 5.5xl 0 CAPACITY gal/stk 2.96 PUMP RATE stks/min 90 FLOW RATE gal/min 534 PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 CRIT-VEL FT/MIN 2. FIO00 5.5x10 2.96 90 TOTAL 2450 psi at stl~min psi at stk/min ANN-VOL BBLS 146 210 0 6 DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 I D-inches 4.276 3. 0 2.875 CAP-bbls/ft .01776 .0087 .0080 D I S P-bbls/ft .0075 .0181 .0542 L E N G T H-ft 6840 518 225 WE IG HT-Ibs/ft 19.5 49.5 149 PIPE DATA CASING: COND SURF DEPTH 110 2827 20.0 9.625 19.12 8.835 · 355 .0758 .0192 .0142 80 2827 91.5 40# REMARK~ AND RECOMMENDATIONS Mw GPM JETS fi/mi = sec/std DRILLED FROM 7511' TO 7583' T.D. CIRCULATED SWEEP AND MONITORED WELL· SHORT TRIPPED TO 6980' WITH 1027 UNITS SHORT TRIP GAS FROM ZONE AROUND 2950', 290 UNITS FROM BOTI-OM. CIRCULATED AND CONDITIONED MUD. ZONE AT 2950' GAVE 980 UNITS FROM WORKING PIPE WHILE CIRCULATING. DROPPED ESS. PULLED OUT OF HOLE AND RIGGED UP SCHLUMBER. MAKING FIRST E-LOG RUN AT REPORT TIME. ,ADT DEPTH 7583' (7017' TVD) OPERATION E-LOG FOOTAGE 0 sr.. fy-sun DR,LUNG SERV,CES LOGGING SYSTEt o A DFESSER I~DUSTRES INC. COIVtOANY APPUED DRILLING TECHNOLOGY MORNING REPORT NO. 14 DATE Mar 2398 TIME O0 01 OPERATOR BP EXPLORATION CONTRACTOR NABOR$ ALASKADRLG START DATE Mar 9 98 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA LOGGING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet) 100 degrees F SURVEY DATA 7583' MD 7019' TVD 8.74 DEGu AZIM 41.6 LITHOLOGY 90% SILTSTONE 10%SANDSTONE SAMPLE DEPTH 7583 TRIP CHLORIDES NA DRILL RATE ft/hr 6.0 LAG DOWN DP 1795 CORRECTED "D" EXP. 1.35 LAG OFF BOTTOM 5495 SHALE DENSITY g/cc NA EWR Res. NA FORMATION PRESSURE DATA PORE PRESSURE FRACTURE PRESSURE ECD CASING 1261 psi 9.0 2073 psi 14.7 1882 psi 12.8 PPg PPg PPg BOTTOM HOLE OPEN HOLE 3510 psi 9.7~, ppg , psi ppg 5860 psi 16.2 ppg ~ psi ~ ppg 4630 psi 12.8 ppg psi ppg MUD DATA BIT DATA HYDRAUUC DATA TIME 21-MAR-98 00:00 TYPE 6% KCL - CORING FLUID WEIGHT IN 11,.4 FUNNEL VIS. 92 PV/YP 33 ~/31 GELS 6 / 14 pH 8.7 FILT/CAKE APl 2.8 ~2 HP-HT 11 Pm 1.2 Pf/Mf 0.1 [ .7 CHLORIDES ppm 30500 CALCIUM ppm 140 OIL/WATER/SOLIDS 1.0186/13 DAILY/CUM. COST NA 5 x 8.835 DP-CSG 5 X 8.5 DP-HOLE 6.75 X 8.835 DC-CSG 6.75 X 8.5 DC-HOLE LENGTH - FT. 2827 4531 0 225 DP OD-inches 5.0 ID-inches 4.276 CAP-bbls/ft .01776 DISP-bbls/ft .0075 L E N G TH -ft 6840 WEIGHT-Ibs/ft 19.5 HWDP 5.0 u 3.0 .0087 .0181 518 49.5 MW GPM E-LOG WITH SCHLUMBERGER. JEfS BIT NO. 4 TYPE ARC 425 IADC CODE CORE BIT2 SIZE 8.5 JETS .75 TFA DEPTH OUT 7134 ROT HRS. 7.5 FOOTAGE 19 AVG ft/hr 12. 5 GRADE HOLE DEV. COST/FT RPM WOB RR2 DS7OFGNPV PDC-MOTOR 8.5 6X12 .66 TFA INC 17.4 449 25.8 19.59 8.74 3310 254 8O 1 83 (TOT) 10 15-25 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0515 .0459 .0315 .0259 PUMPS 1. SIZE inches CAPACITY gal/s£k PUMP RATE stks/min FLOW RATE gal/rain PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 F 1000 5.5xl 0 2.96 CRIT-VEL FT/MIN 2. FIO00 5.5xl 0 u 2.96 psi at stk/min psi at stk/min ANN-VOL BBLS 146 210 DRILL STRING DC 8.0 2.875 .0080 .0542 225 149 PIPE DATA CASING: COND SURF DEPTH 110 2827 20.0 9.625 19.12 8.835 .355 .0758 .0192 .0142 80 2827 91.5 40# AND RECOMMENDATIONS fi/mi : sec/std ,,, ADT DEPTH OPERATION FOOTAGE 7583' f701 7' TVD) L/D DRILL PIPE 0 sF 'fy-sun DRILLING SERVICES LOGGING SYSTE~,.. A ~ I~DLkSTRIES 1',~3. COtV~ANY APPUED DRILLING TECHNOLOGY MORNING REPORT NO. 15 DATE Mar 24 98, TIME O0 01 OPERATOR CONTRACTOR START DATE BP EXPLORATION NABORS ALASKA DRLG Mar 9 98 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA L~ING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet) 50 7583 1314 1671 7583 80 degrees F SURVEY DATA ,7583' MD 7019' TVD 8.74 DEG.T AZIM 41.6 LITHOLOGY 90% SILTSTONE 10%SANDSTONE SAMPLE DEPTH 7583 TRIP CHLORIDES NA DRILL RATE fi/hr 6.0 LAG DOWN DP 1795 CORRECTED 'D" EXP. 1.35 LAG OFF BOTTOM 5495 SHALE DENSITY g/cc NA EWR Res. NA CASING PORE PRESSURE 1261 psi 9.0 FRACTURE PRESSURE 2073 psi 14.7 ECD 1882 psi 12.8 FORMATION PRESSURE DATA BOTTOM HOLE OPEN HOLE ppg 3510 psi 9.7 ppg psi ppg 5860 psi 16.2 ppg psi ppg 4630 psi 12.8 ppg psi PPg PPg PPg MUD DATA Bff DATA HYDRAUUC DATA TIME 21-MAR-98 00:00 TYPE 6% KCL - CORING FLUID WEIGHT IN 11.4 FUNNEL VIS. 82 PV/YP 27 / 26 GELS 5 / 11 pH 8.7 FILT/CAKE APl 3.1 /1 H P-HT 9.0 Pm 0.9 Pf/Mf 0.05 / 0.7 CHLORIDES ppm 29500 CALCIUM ppm 140 OIL/WATER/SOLIDS 1.0 / 86 /13 DAILY/CUM. COST NA LENGTH - FT. 5 x 8.835 DP-CSG 2827 BIT NO. 4 TYPE ARC 425 IADC CODE CORE BIT2 SIZE 8.5 JETS .75 TFA DEPTH OUT 7134 ROT HRS. 7.5 FOOTAGE 19 AVG ft/hr 12.5 GRADE HOLE DEV. 19.59 COST/FT 3310 RPM 8O WOB 10 RR2 DS70FGNPV PDC-MOTOR 8.5 6X12 .66 TFA INC 17.4 449 25.8 8.74 254 183 (TOT) 15-25 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0515 PUMPS 1. Fl000 2. Fl000 SIZE inches 5.5xl 0 5.5xl 0 CAPACITY gal/stk 2.96 2.96 PUMP RATE stks/min 85 85 FLOW RATE gal/rain 506 TOTAL PRESSURE psi 1850 PD SURF / DS psi ANN / BIT psi JET VELOCITY fi/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED I psi at stk/min RATE 2 psi at stk/min CRIT-VEL FT/MIN ANN-VOL BBLS 146 5 X 8.5 DP-HOLE 4531 .0459 210 0 .0315 0 225 .0259 6 6.75 X 8.835 DC-CSG 6.75 X 8.5 DC-HOLE PIPE DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH 110 2827 OD-inches 5.0 5.0 8.0 20.0 9.625 ID-inches 4.276 3.0 2.875 19.12 8.835 CAP-bbls/ft .01776 .0087 .0080 .355 .0758 D IS P-bbls/ft .0075 .0181 .0542 .0192 .0142 L E N G TH-ft 6840 518 225 80 2827 WE IG HT-Ibs/ft 19.5 49.5 149 91.5 40# MW GPM JETS AND RECOMMENDATIONS fi/mi = sec/std E-LOG WITH SCHLUMBERGER. RUN IN HOLE, CIRCULATE HOJ_~' AT 3080' BELOW SHOE. MAX GAS OF 6046 UNITS. RUN IN HOLE AFTER GAS DROPPED BELOW 1300 UNITS CHECKING FOR FLOW PERIODICALLY. CIRCULATED AND CONDITIONED MUD ON BOTTOM WITH TRIP GAS OF 1671 UNITS FROM JUST BELOW SHOE AND 1314 FROM BOTTOM. DROPPED ESS AND PULLED OUT OF HOLE LAYING DOWN SINGLES. ADT DEPTH 7583' 1701 7' TVD) OPERATION .,R/UP RUN 7" FOOTAGE 0 IOPERATOR BP EXPLORATION CONTRACTOR NABORS ALASKAORLG sp',rry-sun .uG SERV,CES LOE GIA/'E A DPESSER i',i~.IS'[I:~$ IN~C. COIV~ ~ED DRILLING TECHNOLOGY MORNING REPORT NO. ._16 DATE Mar 25 98 TIME O0 01 WELL NAME NW EILEEN #1-02 FIELD/BLOCK P.B.U RIG NAME 18-E AREA NORTHWEST EILEEN LOC. CENTRAL NORTH SLOPE STATE ALASKA START DATE Mar 9 98 L L~ING DATA BACKGROUND CONNECTION NA TRIP FLOWLINETEMP 56 AVG MAX AT GAS GAS DEPTH (units) (units) (feet) NA degrees F SURVEY DATA 7583' MD 7019' TVD 8.74 DEG.~ AZIM 41.6 LITHOLOGY 90% SILTSTONE 10% SANDSTONE SAMPLE DEPTH 7583 TRIP CHLORIDES NA DRILL RATE fL/hr 6.0 LAG DOWN DP 1795 CORRECTED "D' EXP. 1.35 LAG OFF BOTTOM 5495 SHALE DENSITY g/cc NA EWR Res. NA PORE PRESSURE FRACTURE PRESSURE ECD FORMATION PRESSURE DATA CASING BOTTOM HOLE OPEN HOLE 1261 psi 9.0 ppg 3510 psi ,9.7 ppg psi ppg 2073 psi 14.7 ppg 5860 psi 16.2 ppg psi ppg psi ppg psi ppg psi ppg MUD DATA BIT DATA HYDRAULIC DATA 21-MAR-98 00:00 4 RR 2 6% KCL - CORING FLUID TIME TYPE WEIGHT IN 11.4 FUNNEL VIS. 82 PV/YP 27 / 26 GELS 5 / 11 pH 8.7 FILT/CAKE APl 3.1 /1 H P-HT 9.0 Pm 0,9 Pf/Mf 0.05 / 0.7 CHLORIDES ppm 29500 CALCIUM ppm 140 OIL/WATER/SOLIDS ,.1.0/86~13 DAILY/CUM. COST NA u LENGTH - FT. 5 x 8.835 DP-CSG 2827 '5 X 8.5 DP-HOLE '45~1 6.75 X 8.835 DC-CSG ,,, 6.75 X 8.5 DC-HOLE __ o 225 BIT NO. TYPE IADC CODE SIZE JETS DEPTH OUT ROT HRS. FOOTAGE AVG fi/hr GRADE HOLE DEV. COST/FT RPM WOB ARC 425 CORE BIT 2 8.5 8.5 .75 TFA 6X12 .66 TFA 7134 INC 7.5 17.4 19 449 12.5 25.8 8.74 19.59 3310 80 10 PUMPS 1. F 1000 DS7OFGNPV SIZE inches 5.5xl 0 PDC-MOTOR CAPACITY gal/stk 2.96 PUMP RATE stks/min FLOW RATE gal/min PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT lbs BIT HP 254 HP RATIO / HP/IN2 183 {TOT} REDUCED 1 15-25 RATE 2 ANNULAR DATA VOLUME BBL$/FT. VELOCITY FT/MIN · 0515 .'0459 .0315 .0259 CRIT-VEL FT/MIN DRILL STRING DP HWDP DC OD-inches 5.0 5.0 8.0 ! ID-inches 4.276 3.0 2.875 CAP-bbls/ft .01776 .0087 .0080 DISP-bbls/ft .0075 .0181 .0542 L E N G TH-ft 6840 518 225 WEI G HT-Ibs/ft 19.5 49.5 149 2. FIO00 5. 5xl 0 2.96 STATIC LAST 24 HRS psi at stk/min psi at stk/min ANN-VOL BBLS 146 STATIC PIPE DATA 210 O. 6 AND RECOMMENDATIONS CASING: COND SURF DEPTH 110 2827 20.0 9.625 19.12 8.835 .355 .0758 · 0192 .0142 80 2827 91.5 40# ,,, MW GPM J~-~S fi/mi = sec/std E-LOG WITH SCHLUMBERGER. NO CIRCULATION LAST 24 HOURS ADT DEPTH 7583' f701 7' TVD) OPERATION R/UP RUN 7" FOOTAGE 0 sF - -ry-s u n _., s L O dTI/VG ...q Y...qTEII,,,. A DPE_S~E~ I',DUS~S ff'~. CON. ANY APPUED DRIllING TECHNOLOGY MORNING REPORT NO. 17 DATE Mar 2698 TIME O0 01 OPERATOR BP EXPLORATION CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 WELL NAME NW EILEEN #1-02 FIELD/BLOCK RIG NAME 18-E AREA LOC. CENTRAL NORTH SLOPE STATE P.B.U NORTHWEST EILEEN ALASKA L~ING DATA BACKGROUND CONNECTION NA TRIP FLOWLINE TEMP 60 AVG MAX GAS GAS (units) (units) NA 655 AT DEPTH (feet) degrees F SURVEY DATA 7583' MD 7019' TVD 8.74 DEG.~ AZIM 41.6 LITHOLOGY 9O% SILTSTONE 10% SANDSTONE SAMPLE DEPTH 7583 TRIP CHLORIDES NA DRILL RATE ft/hr NA LAG DOWN DP CORRECTED "D' EXP. NA LAG OFF BOTTOM 5 SHALE DENSITY g/cc NA EWR Res. .NA CASING PORE PRESSURE 1261 psi 9.0 FRACTURE PRESSURE 2073 psi 14.7 ECD psi FORMA110N PRESSURE DATA BOTTOM HOLE OPEN HOLE ppg 3510 psi 9.7 ppg psi ppg ,5860 psi 16.2 ppg psi ppg psi ppg psi PPg PPg PPg TIME TYPE WEIGHT IN FUNNEL VIS. PV/YP GELS pH FILT/CAKE APl HP-HT Pm Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST MUD DATA 21-MAR-98 00:00 6% KCL - CORING FLUID 11.4 82 27 / 26 5/11 8.7 3.1 /1 9.0 0.9 0.05 { 0.7 29500 140 1.0/86/13 NA BIT DATA BIT NO. 4 TYPE ARC 425 IADC CODE CORE BIT2 SIZE 8.5 JETS .75 TFA DEPTH OUT 7134 ROT HRS. 7.5 FOOTAGE 19 AVG ft/hr 12.5 GRADE HOLE DEV. 19.59 COST/FT 3310 RPM 80 WOB 10 HYDRAUUC DATA RR 2 PUMPS 1. DS7OFGNPV SIZE inches P DC-MOTOR CAPACITY gal/stk 8.5 PUMP RATE stks/min 6X12 .66 TFA FLOW RATE gal/rain ~ PRESSURE psi 17.4 PD SURF / DS psi 449 ANN / BIT psi 25.8 JET VELOCITY ft/sec JET IMPACT lbs 8.74 BIT HP 254 HP RATIO / HP/IN2 83 (TOT) REDUCED 1 15-25 RATE 2 F 1000 5.5xl 0 2.96 2. FIO00 5.5xl 0 2.96 psi at stk/min psi at stk/min 5 x 8.835 DP-CSG LENGTH - FT. 2827 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN .0515 CRIT-VEL FT/MIN ANN-VOL BBLS 5 X 8.5 DP-HOLE 4531 .0459 .0315 .0259 6.75 X 8.835 DC-CSG 0 '6.'75 X 8.5 DC-HOLE 225 DP HWDP DC OD-inches 5.0 5.0 8.0 I D-inches 4.276 3.0 2.875 CAP-bbls/ft .01776 .0087 .0080 ,,, DIS P-bbls/ft .0075 .0181 .0542 LE N GTH-ft 6840 518 225 WEIGHT-Ibs/ft 19.5 49.5 149 · PIPE DATA DRILL STRING CASING: DEPTH COND SURF 110 2827 20.0 9.625 19.12 8.835 .355 .0758 .0192 .0142 80 2827 91.5 40# REMARKS AND RECOMMENDATIONS MW GPM J~- IS RIGED UP AND RUN 7" LINER, AND CEMENTED, mAX GAS WHILE RUNNING LINER 655 UNITS sec/std ,ADT DEPTH .7583' {7017' TVD) OPERATION CLEAN OUT LINER FOOTAGE 0 OPERATOR BP EXPLORATION sp,-"ry-sun ~'"~- ,~ SERVICES LOGGING SYSTEI~:' APPLIED DRILMNG TECHNOLOGY MORNING REPORT NO. 18 DATE Mar 27 98 TIME O0 01 WELL NAME NW EILEEN#1-02 FIELD/BLOCK P.B.U CONTRACTOR NABORS ALASKADRLG START DATE Mar 9 98 RiG NAME 1 8-E LOC. CENTRAL NORTH SLOPE STATE NOHIHWESI I-ILEEN ALASKA L~ING DATA BACKGROUND CONNECTION NA TRIP FLOWLINE TEMP 60 AVG MAX AT GAS GAS DEPTH (units) (units) (feet) NA 21 degrees F SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM ,7583' MD 7019' TVD 8.74 DEG.~ AZIM 41.6 9O% SILTSTONE 10%SANDSTONE 7583 NA DRILL RATE ft/hr NA CORRECTED 'D' EXP. NA SHALE DENSITY g/cc NA EWR Res. NA PORE PRESSURE FRACTURE PRESSURE ECD FORMA'[](~ PRESSURE DATA CASING BOTTOM HOLE OPEN HOLE 1261 psi 9.0 ppg 3510 psi 9.7 ppg psi ppg 2073 psi 14.7 ppg ,5860 psi 16.2 ppg psi ppg psi ppg psi ppg psi ppg MUD DATA BIT DATA HYDRAULIC DATA TIME TYPE WEIGHT IN FUNNEL VIS. PV/YP GELS pH FILT/CAKE APl HP-HT Pm Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST DP-CSG DP-HOLE LENGTH-FT. BIT NO. TYPE IADC CODE SIZE JETS DEPTH OUT ROT HRS. FOOTAGE AVG fi/hr GRADE HOLE DEV. COST/FT RPM WOB 1 ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN PUMPS 1. SIZE inches CAPACITY gal/stk PUMP RATE stks/min FLOW RATE gal/min PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 C RI'I-'-VE L FT/MIN F 1000 5.5xl 0 2.96 2. Fl000 5.5xl 0 2.96 psi at stk/min psi at stk/min ANN-VOL BBLS DC-CSG OD-inches ID-inches CAP-bbls/ft D IS P -b bls/ft LENGTH-ft WEIGHT-Ibs/ft DC-HOLE PIPE DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH REMARKS AND RECOMMENDA11ONS MW GPM JEIS fi/mi = ,, COMPLETED CEMENTING LINER, PICKED UP 31/2' DRILL PIPE, RIH TO CLEAN OUT LINER. MAX GAS DRILLING OUT LINER 21 UNITS. sec/std ,, ,ADT DEPTH OPERATION FOOTAGE 7583' (701 7' TVD} RUN 31/2' TUBING 0 sperry-sun s E R v,c E s L O GI/VG $ Y$ TE/J¢,, ~Ri~, ._R N3USTRES ~lC. COk~ANY APPUED DRIllING TECHNOLOGY MORNING REPORT NO. 19 DATE Mar 27 98 TIME O0 01 OPERATOR CONTRACTOR START DATE BP EXPLORATION NABORS ALASKA DRLG Mar 9 98 WELL NAME NW EILEEN #1-02 RIG NAME 1 8-E LOC. CENTRAL NORTH SLOPE FIELD/BLOCK AREA STATE P.B,U NORTHWEST EILEEN ALASKA LOGGING DATA BACKGROUND CONNECTION TRIP FLOWLINE TEMP AVG MAX AT GAS GAS DEPTH (units) (units) (feet) NA NA 54 SURVEY DATA LITHOLOGY SAMPLE DEPTH TRIP CHLORIDES LAG DOWN DP LAG OFF BOTTOM degrees F FORMATION PRESSURE DATA DRILL RATE ft/hr NA CORRECTED 'D' EXP. NA SHALE DENSITY g/cc NA EWR Res. NA CASING PORE PRESSURE 1261 psi 9.0 FRACTURE PRESSURE 2073 psi 14.7 ECD psi BOTTOM HOLE ppg 3510 psi 9.7 ppg ppg 5860 psi 16.2 ppg ppg psi ppg OPEN HOLE psi ppg psi ppg psi ppg TIME TYPE WEIGHT IN FUNNEL VIS. PV/YP GELS pH FILT/CAKE APl HP-HT Pm Pf/Mf CHLORIDES ppm CALCIUM ppm OIL/WATER/SOLIDS DAILY/CUM. COST DP-CSG MUD DATA DP-HOLE BIT DATA HYDRAUUC DATA BIT NO. TYPE IADC CODE SIZE JETS DEPTH OUT ROT HRS. FOOTAGE AVG ft/hr GRADE HOLE DEV. COST/FT RPM WOB PUMPS 1. SIZE inches CAPACITY gal/stk PUMP RATE stks/min FLOW RATE gal/rain PRESSURE psi PD SURF / DS psi ANN / BIT psi JET VELOCITY ft/sec JET IMPACT lbs BIT HP HP RATIO / HP/IN2 REDUCED 1 RATE 2 F 1000 5.5xl 0 2.96 2. FIO00 5.5xl 0 2.96 psi at stk/min psi at stk/min LENGTH-FT. ANNULAR DATA VOLUME BBLS/FT. VELOCITY FT/MIN CRIT-VEL FT/MIN ANN-VOL BBLS DC-CSG DC-HOLE OD-inches ID-inches CAP-bbls/ft DIS P-bbls/ft LENGTH-ft WEIGHT-Ibs/ft PIPE DATA DRILL STRING CASING: COND SURF DP HWDP DC DEPTH MW GPM JETS REMARKS AND RECOMMENDATIONS fi/mi = sec/std , ,, CLEAN OUT LINER, POOH LAY DOWN 31/2' DRILL PIPE, RUN CASING LOGS, PICK UP AND RUN 3 1/2' TUBING. ADT BP Exploration (Alaska),/nc. NW Eileen ~-02 Prudhoe Bay Report Date Logged: Run Number: 2t-Mar-98 one a, b & c Top Log Interval: Bottom Log Interval: Bit Size: Type Fluid: Density: 5920.00 6215.00 6 in. Baradrill 10 lb/gal Field Engineer: V. Lomax Log Analyst: N. Hewitt NWE 1-02 RF'I' PROCESSING & INTERPRETATION REPORT by Schlumberger GeoQuest. Table of Contents 1. SUMMARY AND CONCLUSION .......................................................................................... 1 2. TOOL THEORY AND METHODOLOGY ............................................................................ 2 2.1 2.2 2.3 TOOL THEORY ........................................................................................................................ 2 INTERPRETATION THEORY ...................................................................................................... 3 PRESSURE GRADIENTS ............................................................................................................ 4 3. PRESSURE GRADIENT PLOT .............................................................................................. 5 4. PRETEST PRESSURE -TIME PLOTS .................................................................................. 6 ;'ld llll I i il~l:l i~ [:l ~ GeoQuest NWE 1-02 RFT Processing & Interpretation .BP Exploration Alaska Inc. Summary and Conclusion This report includes some basics of Repeat Formation Tester measurements and describes the processing and interpretation done on NWE 1-02. The RFT tool was mn over the reservoir bodies to determine: * Reservoir Pressure, * Pressure Gradient. * Formation Fluid Mobility, * and identify permeable zones The RFT data quality control shows the tool has been correctly logged in this well. Because of the unconsolidated grain texture of the reservoir, a Normal probe was used. The tests generally fall into 4 categories: * Good Tests in very permeable zones * Tests in Low Permeability Rock with insufficient time to develop flow regime (Limited Drawdown) * Dry Tests * Seal Failures Several of the RFr pre-test measurements were unstable due to temperature change in early time, as the tool had not been in the well long enough to warm up. These pretests were eliminated from the study. As well, one series of tests needed to be recalibrated after the job. These are included in this report. Several tests were not identified as radial or spherical flow in the field, possibly due to probe seating and/or partial seal failures. This destabilises the 'At vs. Ap' plot for the first few seconds, causing the automatic identification of flow regime to fail. Since in many cases the flow regime is not idemified automatically the formation pressure reported on the field print was simply the last measured pressure during the pre-test. In this report, each profile was n~anually analysed and, if appropriate, the flow regime was identified and an extrapolation to true formation pressure made. The inverse time pro£fles on a few tests indicate behaviours linked to unconsolidated rock: probe movement, and/or frees blocking the probe, etc. In a few tests an exponential increase in pressure late in time indicates possible seal failure. A positive indicator of this is the last buildup pressure much higher than expected formation pressure. Again, these inappropriate measurements were eliminated from the study. The tests indicated as 'limited drawdown' do not have sufficient time to devdop spherical nor radial flow, thus extrapolated formation pressure on these pre-tests is not possible. The pressure profile is provided in log format. The gradient suggested on the plot is that of a formation fluid with a density of 0.86 g/cc. The method indicates a large zone where the porosity is interconnected and the fluid type is constant. ~"I~! il llliil!I:] i( !:11 GeoQuest NWE 1-02 RFT Processing & Interpretation BP Exploration Alaska Inc. Tool theory and methodology The RFT Repeat Formation Tester tool withdraws 20 cc. of fluid from the formatiom creating a small drawdown and pressure pulse in the vicinity of the wellbore. The RFT mw data consist of pressure versus time for about 5 min. after the initial drawdown. The pressure versus time data is processed to give a 'At vs. Ap' distribution in real and inverse times. From this distributiom RFT formation pressure, fluid mobility and permeability are derived. Tool Theory There are eight probes available for the RFF, each built to serve a particular formation type. For interpretation purposes, changing the probe type affects only the value of draw-down MOBILITY. In the NWE 1-02 well a Normal probe was used. The auto interpretation program (same program exists in the field unit and in the computing centre) will attempt to identify: * Mud Pressure Before, * Beginning of Pretest, * Beginning of Buildup, * Last Buildup Pressure. * Mud Pressure After. Figure 1 · Pretest Pressure vs. Time and Pressure vs. Atime plot Mud Pressure before ~ 2ooo.o 1000.0 0.0 ~..,/Beginning _~__.~of pretest ~Bleginning of buildup 10~0 200J) 30 The,~ec pretaliun Gan~ol ~> Pmssure(SGF "-- Mud Pressure Last Buildup Pressure Hydlaulicl~olu, Delta-Time,sec ct T~cs:;. ,J Mare Task I Pressure rs, ~me Companion Plot I :b~lODthOd Pressure vs. l~me Plot Curves Right Default Default SGP Mud Pressure Be/ore, psi: ZI;43.411 Mud Pressure After, psi: ZG43.G5 Last marl buildup FI'~.,~I: Z139.34 Drawdown Mobilit3r, mdlCp: 1Z.Z3 Drawdown Permeability, md: $.1Z ~IiC begining of protest and build up, picks based on Quartz gauge. GeoQuest NWE 1-02 RFT Processing & Interpretation BP Exploration Alaska Inc; Interpretation Theory In Figure 1 a smoothed pressure vs Atime plot is shown. This should be a relatively smooth curve to avoid misinterpretation of the derivative curves, especially at late time. A smoothing of approximately 4 times the gauge resolution is generally used (.04 psi for the RFT-B strain gauge). Flow regime identification has the objective of identifying Radial and Spherical flow regimes. To do this a plot of first derivative of pressure with respect to the spherical and the radial time functions is used. Figure 2 · Flow Regime Identification Spherical Flow Spherical Slope = 0 Radial SloPle = - 0.5 B Radial Flow Spherical Slope = + 0.5 Radial Slope = 0 Pressure Derivative with rcs thc SPH] the RADIAL time fimction In theory the time during which the flow is purely spherical corresponds to when the pressure derivative with respect to the spherical time function has a slope of 0. The pressure derivative with respect to the radial time function has a slope of-0.5 during spherical flow. Similarly, the time during which the flow is purely radial corresponds to when the pressure derivative with respect to the radial time function has a slope of 0. The pressure derivative with respect to the spherical time function has a slope of +0.5 during radial 'flow. The small green arrows labelled A and B in the plot above indicate the start and stop times of spherical flow, C and D indicate the start and stop times of radial flow. The auto-interpretation is capable of identifying these points when 'the derivatives are relatively smooth. These can be chosen or modified by the analyst. The start and stop times are used to extrapolate to infinite time and thus true formation pressure. The character of the extrapolated line is an indication of mobility. GeoQuest NWE 1-02 RFT Processing & Interpretation .BP Exploration Alaska Inc. lo+04 ~ le+O~ 1e+01 I e+O0 1e+01 1e+02 1e+03 Delta-Tim,,aec _] In a number of the pretests, neither flow regime was established. These are labelled ~Limited Drawdown'. Formation pressure cannot be extrapolated in these pretests. The last recorded buildup pressure is substituted for formation pressure, but is of little value in most cases. Pressure Gradients The Extrapolated Formation Pressure is plotted versus True Vertical Depth in the companion color plot. A best fit to the pressures, excluding the limited drawdown and dry tests is made. An assumption that the interval from 7020 to 7100 ft is a single zone in hydraulic communication was made. All limited dmwdown and dry tests, as well as other suspect test pressures, such as the test at 7083 ft showing high pressure, were excluded. The remaining pressures were included in the gradient calculation. The red line is the result. The line has a gradient of 0.3785 psi/ft corresponding to a :fluid density of 0.86 g/cc. The borehole fluid pressure gradient is 0.6185 psi/ft corresponding to a fluid density of 11.75 lb/gal. Also shown on the plot is mobility in mD/cP. This is calculated for the Normal probe and 20cc chamber volume and is based on a summation of (At x Ap) over the entire time of the test. GeoQuest Company : BP Exploration (Alaska), Inc. File : Prudhoe Bay Data Set We. : NWEf-02 Date : Dump Date: Dump Time: : Repeat Formation Tester !"/, LAST Extrapolated File Test TVD Test Mud Before Mud After Build Up Formation Draw Down Depth ~'$ Type Pressure Pressure Pressure Pressure Mobility ft ff (SGP) (SGP) (SGP) (SGP) (SGP) .. !'i,,',/' ,,/,' ...... ,, '", ,,=,,/,',,, , '?,' ,,;,, ...... ;';'r ,' ,,i~-"m'""lr`.- ..... :,"~, ....... '"" "~'~'i ''~ "~. I'":' ~'' "" "~' J" ', ....... i"'"'1 ';';'l' !~ '~ ........ , ,, ,,,,,1:~,1,,,,~ ~',. ~1" :'~''' ,,L'",,,,' ',,,~,,,: ',, ,'1,,~' "1,,' ~':':','~.,':~ ' "",;' !''', 'J'"', ,,;"' '/'''',' ,',,", ",," .... ,~,,, ~,,~", I, '"'"; ,,,'""',,',""'" ~-'-~, ,. ,,rr ',',,~,'; '" ' "', ?'',' ~''~/~'' ~, !;113 71''1'' ?'' ''il ~:'~ ,'la" 7 ",i,':,'¥ ",,,, ,'"" ",~ '~,";":'"'~,:,, ,' """ .... ,," ' ', i'" ,' :,' : '"i ",'~ 157 3026.97 2781.60 Normal 1732.11 1731.29 1274.96 1274.96 20.63 158 3041.19 2794.19 Normal 1739.01 1739.21 1279.44 1279.44 16.95 63 3339.96 3058.58 Normal 1902.97 1902.47 1387.29 1387.29 389.35 64 3951.88 3600.89 Dry 2235.39 2235.38 -7.82 0.00 0.00 65 3952.23 3601.20 Dry 2234.68 2234.61 -8.54 0.00 0.00 ',, 66 4341.01 3947.43 Normal 2446.77 2446.87 1777.68 1777.68 155.04 67 4488.07 4078.33 Normal 2525.87 2525.61, 1832.72 1832.72 285.48 68 4754.96 4313.46 Limited 2668.85 2668.98 1908.60 1908.60 2.06 142 7021.51 6388.10 Dry 3876.21 3876.02 -0.77 0.00 0.00 141 7022.12 6388.71 Dry 3877.51 3876.61 -0.69 0.00 0.00 144 7022.62 6389.20 Normal 3877.28 3877.41 919.59 919.59 133.59 145 7026.02 6392.55 Normal 3879.60 3879.75 3441.39 3441.39 48.67 147 7030.55 6391.01 Normal 3882.34 3882.59 3443.19 3443.19 513.66 148 7032.07 6398.5£ Normal 3883.69 3883.66 3444.02 3444.02 64.02: 149 7034.03 6400.44 Normal 3884.85 3884.98 3444.91 3444.91 53.33 72 7038 6404.35 Normal 3927.68 3927.98 3442.54 3442.54 108.48 150 7038.02 6404.37 Normal 3887.45 3887.28 3446.10 3446.10 29.73 151 7042.99 6409.27 Normal 3890.26 3890.13 3448.1Z 3448.34 9.40 152 7045.031 6411.28 Normal 3891.31 3891.39 3449.16 3452.32 19.71 73 7045.1; 6411.37 Normal 3930.96 3931.54 3445.09 3445.09 43.90 153 7050.95 6417.11 Normal 3894.95 3894.74 3452.91 3452.91 2.39 154 7060.98 6427.00 Normal 3900.76 3900.89 3455.21 3457.82 14.98 155 7062.93 6428.9; Normal 3901.99 3902.13 3456.2; 3459.67 13.31 75 7063.08 6429.07 Normal 3941.35 3942.13 3452.11 3454.16 12.12 76 7083.1 6448.79 Normal 3953.58 3953.60 3473.53 3473.53 2.01 78 7169.54 6533.95 Normal 4004.98 4005.63 3488.24 3508.92 4.23 79 7368.11 6729.68 Normal 4122.81 4123.83 3429.89 3429.89 561.74 File 157 21 -MAR-1998 Pretest 3 (Normal) Depth, ft: 3026.97 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 1732.11 Mud Pressure after retracting, psi: 1731.29 Last build-up Pressure, psi: 1274.96 Draw-down Mobility, md/Cp: 20.63 2000.0 o o o o o o o ~ 1000.0 0.0 0.0 100.0 200.0 300.0 4o0.01 Time,sec1 -- Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) / 600.0 700.0 Hydraulic Motor Speed 1 Auto-Polaris version 3.90 07-May-1998 17:29:34 File 157 21-MAR-1998 Pretest 3 (Normal) Depth, ft: 3026.97 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Slrain 1274.96 1386.0 Raw Pressure (SGP) j Smoothed Pressure (SGP) " 1385.0 1384.0 1383.0 1382.0 1381.0 1380.0 0.0 100.0 200.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 300.0 Auto-Polaris version 3.90 400.O 07-Ma¥-199B 17:29:35 File 157 21-MAR-1998 Pretest 3 (Normal) Depth, fi: 3026.97 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+03 le+02 le+01 le+00 © Sherical Derivative (SGP) I [] Radial Derivative (SGP) Q O O O C3 [3 0 U [] 0 0 [] 0 0 0 0 [3 0 le+00 le+01 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 07-May- 1998 17:29:35 File 158 21-MAR-1998 Pretest 4 (Normal) Depth, fi: 3041.19 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 1739.01 Mud Pressure after retracting, psi: 1739.21 Last build-up Pressure, psi: 1279.44 Draw-down Mobility, md/Cp: 16.94 2000.0 lOO0.0 0.0 0.0 100.0 200.0 Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B($GP) Gauge Resolution,psi; 0.04 3oI o Pressure (SGP) -- Hydraulic Motor Speed Auto-Polaris version 3.90 500.0 07-May-1998 17:29:25 File 158 21-MAR-1998 Pretest 4 (Normal) Depth, ft: 3041.19 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Last build-up Pressure, psi: Strain 1279.44 1500.0 Raw Pressure (SGP) I ' Smoothed Pressure (SGP) ' 1490.0 1480.0 0.0 100.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 200.0 Auto-Polaris version 3.90 300.0 07-May-1998 ~ 7:29:27 File 158 21 -MAR- 1998 Pretest 4 (Normal) Depth, ft: 3041.19 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+04 le+03 le+02 le+01 I ~ c, ShedcalDedvative(SGP)l [] Radial Dedvative (SGP) I o o FI ,. le+00 le+00 le+01 le+02 Delta-Time ,sec Probe Type: Conventional probe Pretest I Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Pc>lads version 3.90 07-May-1998 17:29:27 File 63 21-MAR-1998 Pretest 3 (Normal) Depth, ft: 3339.96 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 1902.97 Mud Pressure after retracting, psi: 1902.47 Last build-up Pressure, psi: 1387.29 Draw-down Mobility, md/Cp: 389.35 2200.0 2100.0 0 0 0 0 o¥ o 2000.0 1900.0 c~ 1800.0 :~ 1700.0 Q- 1600.0 1500.0 1400.0 1300.0 1200.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 200.0 07-May-1998 17:33:08 File 63 21-MAR-1998 Pretest 3 (Normal) Depth, ft: 3339.96 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Last build-up Pressure, psi: Strain 1387.29 1387.7 00 ~ ~ ~'~"~.-~ 0 0 0 Raw Pressure (SGP) I ' Smoothed Pressure (SGP) 1387.6 1387.5 1387.4 1387.3 1387.2 1387.1 1387.0 1386.9 1386.8 1386.7 0.0 10.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 20.0 Auto-Polaris version 3.9,0 30.0 07-May-1998 17:33:09 File 65 21 -MAR- 1998 Pretest 5 (Dry Test) Depth, ft: 395~ ..¢.3 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 2234.68 Mud Pressure after retracting, psi: 2234.61 Last build-up Pressure, psi: -8.54 3000.0 2000.0 lOOO.O o.o -lOOO.O 0.o o ~ 0 o o o -- Probe Type: Conventional probe 100.0 Time,sec Pressure (SGP) Hydraulic Motor Speed 200.0 Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 07-Ma¥-lgg8 17:32:52 File 64 21-MAR-1998 Pretest 4 (Dry Test) Depth, ft: 3951.88 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 2235.39 Mud Pressure after retracting, psi: 2235.38 Last build-up Pressure, psh -7.82 3000.0 o 0 0 0 0 0 0 0 __ [] 2000.0 1000.0 0.0 -1000.0 0.0 100.0 Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Po~arts version 3.90 200.0 07-May-1998 17:33.'O0 File 66 21-MAR-1998 Pretest 6 (Normal) Depth, ft: 4341.01 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before selling, psi: 2446.77 Mud Pressure after retracting, psi: 2446.87 Last build-up Pressure, psi: 1777.67 Draw-down Mobility, md/Cp: 155.03 2700.0 oo -- O -- II I -- -- ,o o 0 2600.0 2500.0 2400.0 2300.0 2200.O u) 2100.0 13_ 2000.0 1900.0 1800.0 1700.0 1600.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 200.0 07-Ma¥-199B 17:32:44 File 66 21 -MAR- 1998 Pretest 6 (Normal) Depth, ft: 4341.01 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 1777.67 1781.4 / Raw Pressure (SGP) I Smoothed Pressure (SGP)J : 1781.3 1781.2 1781.1 1781.0 1780.9 1780.8 0.0 10.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.go 20.0 07-May-199§ 17:3Z:45 File 67 21 -MAR- 1998 Pretest 7 (Normal) Depth, ft: 4488.07 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain Mud Pressure before setting, psi: 2525.87 Mud Pressure after retracting, psi: 2525.61 Last build-up Pressure, psi: 1832.72 Draw-down Mobility, md/Cp: 285.48 2600.0 2500.0 oo o 0 ,O · 2400.0 2300.0 c~. 2200.0 u~ 2100.0 2000.0 1900.0 1800.0 1700.0 0.0 100.0 Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 200.0 07-May-1998 17:32:36 File 67 21-MAR-1998 Pretest 7 (NormaL) Depth, fi: 4488.07 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 1832.72 1835.7 1835.6 Raw Pressure (SGP) I Smoothed Pressure (SGP) J " 835.5 835.4 E 1835.3 835.2 1835.1 1835.0 0.0 10.0 20.0 Delta-Time,sec Probe Type ' Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 30.0 Auto-Polaris version 3.90 40.0 07-May-1998 17:32:37 File 68 21-MAR-1998 Pretest 8 (Limited draw-down) Depth, ft: 4754.96 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 2668.85 Mud Pressure after retracting, psi: 2668.98 Last build-up Pressure, psi: 1908.60 Draw-down Mobility, md/Cp: 2.06 3000.0 2000.0 1000.0 0.0 -1000.0 -- 0 ~ -- o o o g o 0 o 0 o __. o o o.o 1 oo.o Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto--Polaris version 3.90 300.0 07-May-1998 17:32:27 File 68 21-MAR-1998 Pretest 8 (Limited draw-down) Depth, ft: 4754.96 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 1908.60 1910.0 1900.0 1890.0 1880.0 10.0 Smoothed Pressure (SGP) ' 20.0 30.0 40.0 50.0 60.0 70.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volurr~,cc; 10.0 Pretest 2 Volume,cc; 10.0 RFT-B($GP) Gauge Resolution,psi; 0.04 Auto-Polaris version 3.90 07-May-1998 17:32:28 File 68 21-MAR-1998 Pretest 8 (Limited draw-down) Depth, ft: 4754.96 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Slrain le+05 le+04 le+03 le+02 le+01 le+00 I I [] Radial Derivative (SGP) o ooo o v o ~ o 0 0 oo O00 ~ r OC le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Aulo-Polaris version 3.90 le+02 07-Ma¥-1 gg8 17:32:29 File 142 21-MAR-1998 Pretest 3 (Dry Test) Depth, ft: 7021.51 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3876.20 Mud Pressure after retracting, psi: 3876.02 Last build-up Pressure, psi: -0.77 4000.0 3000.0 2000.0 1000.0 0.0 -1000.0 0.0 100.0 Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc; 10.0 RFT-B($GP) Gauge Resolution,psi: 0.04 0 0 %o o o 0 i I I Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:31:18 File 141 21-MAR-1998 Pretest 2 (Dry Test) Depth, ft: 7022.12 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Slrain Mud Pressure before setting, psi: 3877.51 Mud Pressure after retracting, psi: 3876.61 Last build-up Pressure, psi: -0.68 4000.0 0 o o 0 0 o o o o _ o o 0 o 0 3000.0 2000.0 Q.. 1000.0 0.0 -1000.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:31:26 File 144 21-MAR-1998 Pretest 5 (Normal) Depth, fi: 7022.62 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3877.28 Mud Pressure after retracting, psi: 3877.41 Last build-up Pressure, psi: 919.58 Draw-down Mobility, md/Cp: 133.59 4000.0 3000.0 · -~ 2000.0 'L 1000.0 0.0 0.0 100.0 200.0 300.0 4oo.ol Time,sec Probe Type ' Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) I 600.0 700.0 Hydraulic Motor Speed I Auto-Polaris version 3.90 07-May-1998 17:31:04 File 144 21-MAR-1998 Pretest 5 (Normal) Depth, fi: 7022.62 BP EXPLQRATIQN (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Last build-up Pressure, psi: 919.58 3450.0 · ~ 3440.0 r-- 3430.0 Smoothed Pressure (SGP) ' ~ 3420.0 fy' 3410.0 0.0 10.0 20.0 30.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 40.0 Auto-Polaris version 3.90 50.0 07-Ma¥-lgg8 17:31:05 File 144 21 -MAR- 1998 Pretest 5 (Normal) Depth, fi: 7022.62 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+02 le+01 le+00 le-01 1 e-02 le-03 I © Sherical Derivative [] Radial Derivative (SGP) 0 o 1 e-04 1 e+00 Probe Type · Conventional probe Pretes~ 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 1 e+01 1 e+02 Delta-Time ,sec RFT-B($GP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 07-May-1998 17:31:06 File 145 21-MAR-1998 Pretest 6 (Normal) Depth, fl: 7026.02 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Slrain Mud Pressure before setting, psi: 3879.60 Mud Pressure after retracting, psi: 3879.75 Last build-up Pressure, psi: 3441.39 Draw-down Mobillly, md/Cp: 48.67 4000.0 3900.0 3800.0 3700.0 3600.0 3500.0 Z o[.. __ -- -- g · 3400.0 3300.0 3200.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 / Pressure (SGP) J Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-Ma¥-1998 17:30:56 File 145 21 -MAR-1998 Pretest 6 (Normal) Depth, It: 7026.02 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Last build-up Pressure, psi: Strain 3441.39 3449.0 Raw Pressure (SGP) I Smoothed Pressure (SGP) I ~ 3448.0 3447.0 3446.0 0.0 10.0 20.0 30.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest Z Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 40.0 07-May-1998 17:30:57 File 145 21-MAR-1998 Pretest 6 (Normal) Depth, ['t: 7026.02 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain le+02 le+01 le+00 le-01 1 e-02 le-03 I I [] Radial Derivative (SGP) . ..,-c~ le+00 le+01 Delta-Time,sec Probe Type · Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-Ma¥-1998 17:30:57 File 147 21-MAR-1998 Pretest 8 (Normal) Depth, ft: 7030.55 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3882.34 Mud Pressure after retracting, psh 3882.59 Last build-up Pressure, psi: 3443.19 Draw-down Mobility, md/Cp: 513.66 4000.0 3900.0 3800.0 3700.0 3600.0 O o o 0 · 3500.0 3400.0 3300.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B($GP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17;30;47 File 147 21 -MAR-1998 Pretest 8 (Normal) Depth, ft: 7030.55 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Last build-up Pressure, psi: 3443.19 3443.5 __ 0 o o Oo o o % o y° o ~ O0 0 oo o ° °~ ? o° °° Raw Pressure (SGP) Smoothed Pressure (SGP) " 3443.4 3443.3 3443.2 3443.1 0.0 10.0 20.0 30.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 40.0 50.0 Auto-Polaris version 3.90 07-May-1998 17:30:48 File 147 21 -MAR-1998 Pretest 8 (Normal) Depth, fi: 7030.55 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+03 le+02 le+01 le+00 1 e-01 I I O Shedcal Derivative (SGP) [] Radial Derivative (SGP) O u o 9 9 121 ~3 ~3 o le-02 le+00 le+01 le+02 Delta-Time,sec Probe Type: Conventional probe Prelesl 1 Volume,cc: 10.0 Pretes[ Z Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 07-May-199§ 17:30;49 File 148 21-MAR-1998 Pretest 9 (Normal) Depth, f't: 7032.07 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3883.69 Mud Pressure after retracting, psi: 3883.66 Last build-up Pressure, psi: 3444.02 Draw-down Mobility, md/Cp: 64.02 4000.0 3900.0 3800.0 3700.0 3600.0 Q.. 3500.0 3400.0 3300.0 3200.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:30:39 File 148 21-MAR-1998 Pretest 9 (Normal) Depth, ft: 7032.07 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 3444.02 3449.0 · ~ 3448.0 Raw Pressure (SGP) I Smoothed Pressure (SGP) r-' 3447.0 3446.0 0.0 10.0 20,0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volurr~,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B($GP) Gauge Resolution,psi: 0.04 30.0 Auto-Polaris version 3.90 40.0 07-May-1998 17:30:40 File 148 21 -MAR-1998 Pretest 9 (Normal) Depth, ft: 7032.07 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain le+02 le+01 le+00 le-01 1 e-02 le-03 1 e-04 [] Radial Derivative (SGP) [] [] °~0 ~p 0 le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-May-1998 17:30:40 File 149 21-MAR-1998 Pretest 10 (Normal) Depth, Ct: 7034.03 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3884.85 Mud Pressure after retracting, psi: 3884.98 Last build-up Pressure, psi: 3444.91 Draw-down Mobility, md/Cp: 53.33 4000.0 3900.0 __ -- o o o o o 3800.0 3700.0 3600.0 3500.0 3400.0 3300.0 3200.0 0.0 100.0 Time,sec Probe Type: ConventJonal probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc; 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris Yer~ion 3.90 300.0 07-May-1998 17:30:31 File 149 21-MAR-1998 Pretest 10 (Normal) Depth, ft: 7034.03 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain Last build-up Pressure, psi: 3444.91 3447.0 3446.0 3445.0 3444.0 -- '?" ~'?-'v - 0000~00- ~ ~0~ ~ 0 O0 © Raw Pressure (SGP) I ' -- Smoothed Pressure (SGP) ' 0.0 10.0 20.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 30.0 Auto-Polaris version 3.90 40.0 07-May-1998 17:30:32 File 149 21-MAR-1998 Pretest 10 (Normal) Depth, it: 7034.03 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain le+02 le+01 le+00 1 e-01 le-02 I i [] Radial Derivative (SGP) o 79 O u []"~ [:3 I 0 ~ 0 ~ ~ le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-May-1998 17:30;32 File 72 21-MAR-1998 Pretest 11 (Normal) Depth, fi: 7038.00 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3927.68 Mud Pressure aller relracting, psi: 3927.98 Last build-up Pressure, psi: 3442.54 Draw-down Mobility, md/Cp: 108.48 4100.0 4000.0 3900.0 3800.0 Q-3700.0 3600.0 3500.0 3400.0 3300.0 3200.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:32:t9 File 72 21-MAR-1998 Pretest 11 (Normal) Depth, ft: 7038.00 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Last build-up Pressure, psi: 3442.54 3443.0 3442.0 O0°o 0oo o o 00o00 0o0 ooO~-~-~'~K'~" °o o 0 °°o o o0 o 0 v~O o ~ ~v,o=~O00 O0V o0O0~ Raw Pressure (SGP) I Smoothed Pressure (SGP) } 3441.0 0,0 10.0 20.0 30.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 07-May-1998 17:32:19 File 72 21 - MAR- 1998 Pretest 11 (Normal) Depth, ft: 7038.00 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+02 le+01 le+00 le-01 1 e-02 le-03 © Sherical Derivative [] Radial Derivative (SGP) v o o 1 e+00 1 e+01 Delta-Time,sec le+02 Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 07-May-1998 17:32:20 File 150 21 - MAR-1998 Pretest 11 (Normal) Depth, ft: 7.038,02, BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3887.45 Mud Pressure after retracting, psi: 3887.28 Last build-up Pressure, psi: 3446.10 Draw-down Mobility, md/Cp: 29.73 4000.0 3900.0 3800.0 3700.0 c~3600.0 3500.0 el_ 3400.0 3300.0 3200.0 3100.0 3000.0 0.0 100.0 Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:30:24 File 150 21 -MAR- 1998 Pretest 11 (Normal) Depth, ft: 7038.02 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 3446.10 3448.0 · ~ 3447.0 _c: 3446.0 O O ~ 3445.0 Raw Pressure (SGP) Smoothed Pressure (SGP) 3444.0 0.0 10.0 20.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 30.0 Auto-Polaris version 3.90 40.0 07-May- 1998 17:30:25 File 150 21-MAR-1998 Pretest 11 (Normal) Depth, ft: 7038.02 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+03 le+02 le+01 le+00 le-01 le-02 i I O Shedcal Derivative (SGP) I [] Radial Derivative (SGP) I I le+00 le+01 Delta-Time,sec le+02 Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge ResolulJon,psi: 0.04 Auto--Polaris version 3.90 07-May-1998 17:30:25 File 151 21-MAR-1998 Pretest 12 (Normal) Depth, ft: 7042.99 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3890.25 Mud Pressure after retracting, psi: 3890.13 Last build-up Pressure, psi: 3448.14 Draw-down Mobility, md/Cp: 9.40 4000.0 3000.0 2000.0 0 0 0 o 0 o o ~ o <> 0 ?,4 0.0 100.0 Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-Ma?-1998 17:30:15 File 151 21 -MAR- 1998 Pretest 12 (Normal) Depth, ft: 7042.99 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Last build-up Pressure, psi: 3448.14 3449.0 3448.0 3447.0 ~ 3446.O ~ 3445.0 j::: 3444.0 o O E 3443.o 3442.0 3441.0 Raw Pressure (SGP) Smoothed Pressure (SGP) 3440.0 3439.0 0.0 10.0 20.0 30.0 Delta-Time,sec Probe Type · Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 40.0 Auto-Polaris version 3.90 50.0 07-May-1998 17:30:16 File 151 21 -MAR- 1998 Pretest 12 (Normal) Depth, ft: 7042.99 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain From picks on Spherical Derivative: Slope on Spherical: -0.06 Slope on Radial: -0.54 le+03 le+02 1 e+01 le+00 1 e-01 I I I O ShedcalDerivat~ve(SGP)l [] Radial Dedvative (SGP) 0 0 00 0 0 0 0 0 E3 F9 (3 00 ~ ~,09' le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-May-199B 17:30:17 File 151 21-MAR-1998 13.2 Pretest 12 (Normal) Depth, ft: 7042.99 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Delta Time (sec) 23.4 Interpreted Gauge: Strain Last Build-up Pressure, psi: 3448.14 Extrapolated Pressure, psi: 3448.34 Slope, psi*sqd(sec): -5.03 Build-up Mobility,md/Cp 6.38 3448.4 3448.3 3448.2 .m .....CO 3448.1 Q- 3448.O 3447.9 3447.8 0.200 Probe Type: Conventional probe o O0 o 0 o o o 0 0 0 ~0 0.100 Spherical Time, 1/sqrt(sec) 31.2 · 38.4 · '& 49.8 000 0 O0 8°goO Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Inf 3448.4 3448.3 3448.2 3448.1 3448.0 3447.9 3447.8 0.000 Auto-Polaris version 3.90 07-May-1998 17:30:17 File 152 21 -MA R- 1998 Pretest 13 (Normal) Depth, fi: 7045.03 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3891.31 Mud Pressure after retracting, psi: 3891.39 Last build-up Pressure, psi: 3449.16 Draw-down Mobility, md/Cp: 19.71 4000.0 3000.0 o oo 2000.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:30:06 File 152 21-MAR-1998 Pretest 13 (Normal) Depth, ft: 7045.03 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Last build-up Pressure, psi: Strain 3449.16 3450.0 3449.0 ~ 3448.0 r-- 3447.0 O O E ~ 3446.0 3445.0 3444.0 i Raw Pressure (SGP) Smoothed Pressure (SGP) I 0.0 10.0 20.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 30.0 Auto-Polaris version 3.90 40.0 07-May-1998 17:30:07 File 152 21-MAR-1998 le+03 le+02 le+01 le+00 Pretest 13 (Normal) Depth, fi: 7045.03 Interpreted Gauge: Strain BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 From picks on Radial Derivative: Slope on Spherical: 0.49 Slope on Radial: 0.06 ~ Sherical Derivative (SGP) [] Radial Derivative (SGP) 0 C 00 j~ le-01 le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 le+02 Auto-Polaris version 3.90 07-May-1998 17:30:08 File 152 21-MAR-1998 1.2 3460.0 3450.0 3440.0 3430.0 Pretest 13 (Normal) Depth, ft: 7045.03 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 2.7 Delta Time (sec) & · 3.3 5.1 8.1 Interpreted Gauge: Last Build-up Pressure, psi: Extrapolated Pressure, psi: Slope, psi/cycle: Hodz. Mobility Thickness, 36.3 Strain 3449.16 3452.32 -3.97 14.53 Inf ' 3460.0 3450.0 3440.0 3430.0 3.000 2.000 Radial Time Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 1.000 Auto-Polaris version 3.90 0.000 07-May-1998 17:30:08 File 73 21-MAR-1998 Pretest 12 (Normal) Depth, ft: 7045.12 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWl= 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3930.96 Mud Pressure after retracting, psi: 3931.54 Last build-up Pressure, psi: 3445.09 Draw-down Mobility, md/Cp: 43.90 4100.0 o o oo o o o 4000.0 3900.0 3800.0 3700.0 3600.0 3500.0 3400.0 3300.0 3200.0 3100.0 3000.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-Ma¥-1998 17:32:10 File 73 21 - MAR-1998 Pretest 12 (Normal) Depth, fi: 7045.12 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 3445.09 3446.O Raw Pressure (SGP) I Smoothed Pressure (SGP) I 3445.0 3444.0 3443.0 3442.0 3441.0 0.0 10.0 20.0 30.0 Delta-Time ,sec Probe Type: Convenl~onal probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 40.0 Auto-Polaris version 3.90 50.0 07-May-1998 17:32:11 File 73 21-MAR-1998 Pretest 12 (Normal) Depth, ft: 7045,12 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+02 le+01 le+00 le-01 1 e-02 1 e-03 1 e-04 I O Sherical Derivative [] Radial Derivative (SGP) o o le+00 le+01 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-May-1998 17:32:1 File 153 21 -MAR-1998 Pretest 14 (Normal) Depth, ft: 7050.95 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3894.95 Mud Pressure after retracting, psi: 3894.74 Last build-up Pressure, psi: 3452.90 Draw-down Mobility, md/Cp: 2.39 4000.0 3000.0 2000.0 1000.0 0.0 0.0 100.0 200.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 · 0 0 o 0 0 o 0 0 0 0 0 0 ~ °° 0 Pressure (SGP) Hydraulic Motor Speed 400.0 Auto-Polaris version 3.90 07-May-1998 17:29:59 File 153 21-MAR-1998 Pretest 14 (Normal) Depth, ft: 7050.95 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 3452.90 3900.0 389O.O 3880.0 3870.0 3860.0 ] Raw Pressure (SGP) J Smoothed Pressure (SGP) 1 0.0 100.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 200.0 07-May-1998 17:29:59 File 153 21-MAR-1998 Pretest 14 (Normal) Depth, f-t: 7050.95 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+06 le+05 le+04 le+03 le+02 le+01 I I I <> Shedcal Dedvative (SGP) [] Radial Derivative (SGP) * % (:3 [~ 1~ --..,~.~ ,, le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 le+02 Auto-Polaris version 3.90 le+03 07-May-1998 17:30:00 File 154 21-MAR-1998 Pretest 15 (Normal) Depth, fi: 7060.98 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3900.76 Mud Pressure after retracting, psi: 3900.89 Last build-up Pressure, psi: 3455.21 Draw-down Mobility, md/Cp: 14.98 5000.0 0 o o 0 t 4000.0 3000.0 2000.0 0.0 100.0 Time,sec Probe Type: Convenlional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume~cc: 10.0 RFT-B(SGP) Gau.qe Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 200.0 07-May-1998 17:29:50 File 154 21-MAR-1998 Pretest 15 (Normal) Depth, fi: 7060.98 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Last build-up Pressure, psi: 3455.21 3456.0 3455.0 · G 3454.0 ~ 3453.0 .: 3452.0 o o O3 3451.0 ~ 3450.0 3449.0 3448.0 // Raw Pressure (SGP) Smoothed Pressure (SGP) 0.0 10.0 20.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFf-B(SGP) Gauge Resolution,psi: 0.04 30.0 Auto-Polaris version 3.90 40.0 07-May-1998 17:29:51 File 154 21-MAR-1998 Pretest 15 (Normal) Depth, ft: 7060.98 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain From picks on Spherical Derivative: Slope on Spherical: -0.06 Slope on Radial: -0.51 le+03 le+02 1 e+01 le+00 I I [] Radial Derivative (SGP) O O. O O O, o 0 r-1 121[] UO2Do 00£ DDo~- 1 e+00 1 e+01 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-May- t 998 17:29:5 t File 154 21 -MAR- 1998 3460.0 3450.0 Pretest 15 (Normal) Depth, ft: 7060.98 Interpreted Gauge: Last Build-up Pressure, psi: Extrapolated Pressure, psi: Slope, psl*sqrt(sec): Delta Time (sec) Build-up Mobility,md/Cp 3.9 4.5 5.7 6.9 9.0 12.9 22.8 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Strain 3455.21 3457.82 -20.06 2.57 6.6& 7.8& · 39.6 39.6 3440.0 0.700 0.600 0.500 0.400 0.300 Spherical Time, 1/sqrt(sec) Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 3460.0 3450.0 3440.0 0.200 0.100 0.000 Auto-Polaris version 3.90 07-May-1998 17:29:52 File 155 21-MAR-1998 Pretest 16 (Normal) Depth, ft: 7062.93 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3901.99 Mud Pressure after retracting, psi: 3902.13 Last build-up Pressure, psi: 3456.22 Draw-down Mobility, md/Cp: 13.31 4000.0 ::3 3000.0 2000.0 -- -- 0 0 -- o.o lO0.O Time ,sec Probe Type: Conventional probe Pretesl 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:29:42 File 155 21 -MAR-1998 3460.0 ,...,r"'° 3450.0 I,... Pretest 16 (Normal) Depth, ft: 7062.93 Interpreted Gauge: Strain Last Build-up Pressure, psi: 3456.22 Extrapolated Pressure, psi: 3459.67 Slope, psi*sqrt(sec): -27.30 Delta Time (sec) Build-up Mobility,md/Cp 2.09 3.9 4.5 5.7 6.9 9.0 12.9 22.8 56.1 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 ' 6.0'~ 7.5& &56.1 3440.0 0.700 0.600 0.500 0.400 0.300 Spherical Time, 1/sqrt(sec) Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 3460.0 3450.0 0.200 0.100 3440.0 0.000 Auto-Polaris version 3.90 07-May-1998 17:29:44 File 155 21-MAR-1998 Pretest 16 (Normal) Depth, ft: 7062.93 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 3456.22 3457.0 3456.0 Raw Pressure (SGP) Smoothed Pressure (SGP) I · ~ 3455.0 ~ 3454.0 .c:: 3453.0 0 0 r.D 3452.0 ~ 3451 0 · 3450.0 3449.0 0.0 10.0 20.0 30.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 40.0 50.0 60.0 Auto-Polaris version 3.90 07-May-1998 17:29:42 File 155 21 -MAR- 1998 Pretest 16 (Normal) Depth, ft: 7062.93 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain From picks on Spherical Derivative: Slope on Spherical: -0.03 Slope on Radial: -0.45 le+03 le+02 1 e+01 le+00 I I I O ShericalDedvative(SGP)I [] Radial Derivative (SGP) o o o o o oo oz,,o o~&oo,**~ le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-May-1998 17:29:43 File 75 21 -MAR- 1998 Pretest 14 (Normal) Depth, ft: 7063.08 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 3941.35 Mud Pressure after retracting, psi: 3942.13 Last build-up Pressure, psi: 3452.11 Draw-down Mobility, md/Cp: 12.12 5000.0 0 0 0 4000.0 3000.0 2000.0 0.0 100.0 Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:32:00 File 75 21-MAR-1998 Pretest 14 (Normal) Depth, ft: 7063.08 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 3452.11 3453.0 Raw Pressure (SGP) Smoothed Pressure (SGP) I 3452.0 3451.0 ~3450.0 3449.0 3448.0 3447.0 3446.0 3445.0 3444.0 3443.0 0.0 10.0 20.0 30.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 40.0 50.0 60.0 Auto-Polaris version 3.90 07-Ma¥-1998 17:32:01 File 75 21 -MAR- 1998 Pretest 14 (Normal) Depth, ft: 7063.08 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain From picks on Spherical Derivative: Slope on Spherical: -0.09 Slope on Radial: -0.53 le+03 le+02 le+01 le+00 le-01 © Sherical Derivative (SGP) [] Radial Derivative (SGP) n 0 0 0 0 0 .0 o. oA~,oo¢ooo>oo, oo,~ ,m D 0 C 2 U 0 ]00 IOOc 0 ~ le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-May-1998 17:32:02 File 75 21-MAR-1998 2.1 Pretest 14 (Normal) Depth, ft: 7063.08 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Delta Time (sec) 4.5 Interpreted Gauge: Strain Last Build-up Pressure, psi: 3452.11 Extrapolated Pressure, psi: 3454.16 Slope, psi*sqrt(sec): -14.70 Build-up Mobility,md/Cp 2.47 3460.0 3450.0 Q- 344O.O 3430.0 2.000 6.0& 10.5 & &5' Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 1.000 Spherical Time, 1/sqrt(sec) RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 Inf '~460.0 3450.0 3440.0 3430.0 0.000 07-Ma¥-1998 17:32;02 File 76 21-MAR-1998 Pretest 15 (Normal) Depth, ft: 7083.10 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Slrain Mud Pressure before setting, psi: 3953.58 Mud Pressure after retracting, psi: 3953.60 Last build-up Pressure, psi: 3473.53 Draw-down Mobility, md/Cp: 2.01 5000.0 0 0 0 0 0 0 ~, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4000.0 3000.0 2000.0 1000.0 0.0 -1000.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:31:51 File 76 21-MAR-1998 Pretest 15 (Normal) Depth, fi: 7083.10 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWl= 1-02 Interpreted Gauge: Last build-up Pressure, psi.' Strain 3473.53 4040.0 4030.0 4020.0 4010.0 4000.0 3990.0 I Raw Pressure (SGP) I Smoothed Pressure (SGP) I 0.0 100.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 200.0 07-May-1998 17:31:52 File 76 21 -MAR- 1998 Pretest 15 (Normal) Depth, ft: 7083.10 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain le+05 le+04 le+03 le+02 1 e+01 ~ Sherical Derivative (SGP) [] Radial Derivative (SGP) ° %° o %° , 0 ° le+O0 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 le+02 07-May-1998 17:31:53 File 78 21-MAR-1998 Pretest 17 (Normal) Depth, ft: 7169.54 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 4004.98 Mud Pressure after retracting, psi: 4005.63 Last build-up Pressure, psi: 3488.24 Draw-down Mobility, md/Cp: 4.23 5000.0 4000.0 c~ 3000.0 ,-- Q.. 2000.0 1000.0 0.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) J Hydraulic Motor Speed Auto-Polaris version 3.90 300.0 07-May-1998 17:31:41 File 79 21-MAR-1998 Pretest 18 (Normal) Depth, ft: 7368.11 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Mud Pressure before setting, psi: 4122.81 Mud Pressure after retracting, psi: 4123.83 Last build-up Pressure, psi: 3429.89 Draw-down Mobility, md/Cp: 561.74 4300.0 4200.0 4100.0 4000.0 ~3900.0 3800.0 3700.0 3600.0 3500.0 3400.0 0.0 100.0 Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Pressure (SGP) Hydraulic Motor Speed Auto-Polaris version 3.90 200.0 07-May'-1998 17:31:33 File 79 21-MAR-1998 Pretest 18 (Normal) Depth, ft: 7368.11 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Last build-up Pressure, psi: Strain 3429.89 3430.0 3429.9 0 o O O ~~O O OO o 0 O0 0 ~~0 0 0 o 0 0 o 0 o ~-~'~~o~ ~ o 0° 00' 0 O~ O0 O0 0 0°00 0 o [ ° o , Smoothed Pressure {SGP) .,c: 3429.8 0 o E ~ 3429.7 3429.6 0.0 10.0 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 20.0 Auto-Polaris version 3.90 30.0 07-May- 1998 17:31:34 File 78 21-MAR-1998 1.5 3500.0 3400.0 3300.0 3200.0 Pretest 17 (Normal) Depth, ft: 7169.54 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Delta Time (sec) 2.4 4.5 3.0'a' 4.5 Interpreted Gauge: Last Build-up Pressure, psi: Extrapolated Pressure, psi: Slope, psi'sqd(sec): Build-up Mobility,md/Cp Strain 3488.24 3485.95 -91.38 0.71 Inf 3500.0 3400.0 3300.0 3200.0 3.000 2.000 1.000 Spherical Time, 1/sqrt(sec) Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 0.000 07-May- 'J 998 17:31;43 File 78 21-MAR-1998 5.7 3510.0 3500.0 3490.0 .m o-3480.0 v3470.0 ~ 3460.0 Pretest 17 (Normal) Depth, ft: 7169.54 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Delta Time (sec) 14.4 Interpreted Gauge: Last Build-up Pressure, psi: Extrapolated Pressure, psi: Slope, psi/cycle: Hodz. Mobility Thickness, Strain 3488.24 3508.92 --42.84 0.89 Inf 3450.0 344O.O 3430.0 11.7 ~2.9 · · 72.6 0 O 0 0 0 0 n 2.000 1.000 Radial Time Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 3510.0 3500.0 3490.0 3480.0 3470.0 3460.0 3450.0 3440.0 3430.0 0.000 Auto-Polaris version 3.90 07-May-1998 17:31:44 File 78 21 -MAR- 1998 Pretest 17 (Normal) Depth, ft: 7169.54 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain Last build-up Pressure, psi: 3488.24 3490.0 3480.0 3470.0 3460.0 10.0 20.0 30.0 Raw Pressure (SGP) I Smoothed Pressure (SGP) 40.0 50.0 60.0 70.0 80.0 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 Auto-Polaris version 3.90 07-May-19§8 17:31:42 File 78 21 -MAR- 1998 le+03 le+02 1 e+01 Pretest 17 (Normal) Depth, ft: 7169.54 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-02 Interpreted Gauge: Strain From picks on Spherical Derivative: Slope on Spherical: -0.02 Slope on Radial: -0.46 From picks on Radial Derivative: Slope on Spherical: 0.45 Slope on Radial: -0.07 I I I O ShedcalDedvative(SGP)l [] Radial Dedvafive (SGP) I 0 0000 ]00 1 e+00 le+00 le+01 Delta-Time ,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 le+02 Auto-Polaris version 3.90 07-Ma¥-1998 17:31:43 File 79 21 -MA R- 1998 Pretest 18 (Normal) Depth, fi: 7368.11 BP EXPLORATION (ALASKA), INC. Prudhoe Bay NWE 1-O2 Interpreted Gauge: Strain le+01 le+00 le-01 1 e-02 1 e-03 I [] Radial Derivative (SGP) ____ ~3 0O< O0 o o 0 1 e-04 le+00 le+01 Delta-Time,sec Probe Type: Conventional probe Pretest 1 Volume,cc: 10.0 Pretest 2 Volume,cc: 10.0 RFT-B(SGP) Gauge Resolution,psi: 0.04 le+02 Auto-Polaris version 3.90 07-Ma¥-1998 17:31:35 500 W. International Airport Road Anchorage, Alaska, 99518 1199 Tel: (907) 562-2654 Fax: (907) 563-3309 To~ From: Subject: Date: Bret Chambers/A.Bent/D. Lowe/J.Denis Graham Stuart-Schlumberger WSA "E" line services coordinator NWE 1-02 Corrected RFT data 4/21/98 Bret, Please find attached the corrected RFT field data for well NWE 1-02 This cover note explains what was done to arrive at the final data set which is complete including tests with thermal and seal failures/slow leak/supercharging problems. To aid in understanding the following, please refer in conjunction with the RFT tables at the beginning of the field print. Geoquest will prepare a report with only valid data for clarity. Run la data is played back with new gauge 912 master calibration. Gauge 912 calibration used during the field acquisition was incorrect. Data (Tests 2 and 3 (files 157/158)) are valid Run lb data is original field data. It needs no correction. However tests 8 and 9(files 70 and 71) are thermally unstable and should be discarded. Other points from this data set that could be considered seal failures/slow leak/supercharged are: Tests 12,14,15,17(files 74/76/77/79) Test 17 displays low pressure, but could be valid. Tests 12 and 14 may be supercharged. Test 15 appears to be a seal failure The remainder of the points, tests 2(file 63),tests 5,6,7,10,11,13,16 (:files 66/67/68/72/73/75/78) are valid. Run 2a data is played back with new gauge 912 master calibration. Gauge 912 calibration used during the field acquisition was incorrect. The following data point is not valid test 6 (file 146) The remainder o:f the points: tests 1,2,3,4,5,7,8,9,10,11,12,13,14,15(files 141/142/1143/144/145/147/148/149/1150/151/152/153/154/155) are all valid. Notes: All master calibrations are made with a deadweight tester. Gauge 912 has had 3 calibrations, one on 9/12/96,another on 9/27/97 and the final one on 4/5/98 post job. The first and last calibration agree within lpsi. However the middle calibration is clearly reading higher by 13-16 psi, over the range 3000psi-4000psi at 115degf. It is incorrect. This gauge was used on runs la and run 2a Gauge 913 was used for run lb. It was also recalibrated post job and found to be within 1 psi of the pre job master calibration Please feel free to contact me if you have further comment or input. Regards, CC: Graham Stuart David Nims: Drilling superintendent. Schlumberger North Slope:Tim Smith, Scott Bittner 500 W. International Airport Road Anchorage, Alaska, 99518 1199 Tel: (907) 562-2654 Fax: (907) 563-,3309 To: Bret Chambers/A.Bent/D.Lowe/J.Denis From: Graham Stuart-Schlumberger WSA "E" line services coordinator Subject: NWE 1-02 Corrected RFT data Date: 4/21/98 Bret, Please find attached the corrected RFT fMd data for well NWE 1-02 This cover note explains what was done to arrive at the final data set which is complel including tests with thermal and seal failures/slow leak/supercharging problems. To aid in understanding the following, please refer in conjunction with the RFT tables ~t the begimxing of the field print. Geoquest will prepare a report with only vahd da ta for clarity. Run la data is played back with new gauge 912 master calibration. Gauge 912 calibration used during the field acquisition was incorrect. Data (Tests 2 and 3 (files 157/158)) are valid Run lb data is original field data. It needs no correction. However tests 8 and 9(files 70 and 71) are thermally unstable and should be discarded. Other points from this data set that could be considered seal failures/slow leak/superc arged are: Tests 12,14,15,17(files 74/76/77/79) Test 17 displays low pressure, but could be valid. Tests 12 and 14 may be supercharged. Test 15 appears to be a seal failure The remainder of the points, tests 2(file 63),tests 5,6,7,10,11,13,16 (files 66/67/68/72/73/75/78) are valid. Run 2a data is played back with new gauge 912 master calibration. Gauge 912 calibration used during the field acquisition was incorrect. The following data point is not valid test 6 (file '146) The remainder of the points: tests~~2~3~4~5~7~8~9~~~~~~~~2~~3~~4~~5(fi~es~4~/~42/~43/~44/~45/~47/~48/~49/~5~/~5~/~52/~53/154/~55 ) are all valid. Notes: All master calibrations are made with a deadweight tester. Gauge 912 has had 3 calibrations, one on 9/12/96, another on 9/27/97 and the final on on 4/5/98 post job. The first and last calibration agree within lpsi. However the middle calibration is clearly reading higher by 13-16 psi, over the range 3 30psi-4000psi at ll5degf. It is incorrect. This gauge was used on runs la and run 2a I 500 W. Intemat~onaJ Airport Road Anchorage, Alaska, 99518 1199 Tel: (907) 562-2654 Fax: (907) Gauge 913 was used for run lb. It was also recalibrated post job and found to be withi~ 1 psi of the pre job master calibration Please feel free to contact me if you have further comment or input. Re r s, _ Graham Stuart CC: David Nims: Drilling superintendent. Schlumberger North Slope:Trna. Smith, Scott Bittner 180 Azimuth of hand- picked dips Type Oeat~d Ub'.ot O~c~ } ~ witl~out Tr~ce t Statistics of hand- picked dips 0 180 Azimith of MSD dips Mean Dip: ' . M~./~i~u~.., Statistics of MSD Dips April 8, 1998 Paae - April 8, 1998 Page I BP EXPLORATION, Alaska Date: 06-12-98 Trans# 89204 NW EILEEN LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 I Sw Name ILog TypelRec TypelRec Date Comments (-~-~ NWE1-02 RFT IREP 121-Mar-98 REPEAT FORMATION TESTER BOUND REPORT Please sign and return one copy of this transmittal letter. Thank-you, Nadene Reichert Petrotechnical Data Center ARCO - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips- Paul Robertson DNR - Tim Ryherd AOGCC - Howard Oakland BP - Brett Chambers Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 05-19-98 Trans# 89121 NW EILEEN LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Log Type:Rec Type Rec Date Meas Depth Meas Depth Comments ,Top Base NWE1-02 USIT 'CH 27-Mar-98 2,823. 7,476. ULTRA SONIC CEMENT IMAGER NWE1-02 CMR IOH 21-Mar-98 6,900. 7,580. COMBINABLE MAGNETIC RESONANCE IMAGER RAW DATA NWE1-02 CDN OH 21-Mar-98 2,824. 7,584. PLATFROM EXPRESS DENSITY/NEUTRON GAMMA RAY NWE1-02 CNL OH 21-Mar-98 2,824. 7,574. PLATFROM EXPRESS COMPENSATED NEUTRON GAMMA RAY NWE1-02 SS TVD OH 21-Mar-98 2,824. 7,574. PLATFROM EXPRESS SS TVD LOG NWE1-02 PERF CFI 07-Apr-98 6,800. 7,072. PERFORATING RECORD NWE1-02 AlT OH 21-Mar-98 2,824. 7,574. PLATFORM EXPRESS ARRAY INDUCTION/SP GAbiMA RAY NWE1-02 DSl OH 21-Mar-98 2,824. 7,548. DIPOLE SONIC SHEAR LOG DSl - GPIT-GR NWE1-02 FMS OH 21-Mar-98 6,800. 7,580. FORMATION MICRO IMAGER RAW DATA NWE1-02 PERF CH 02-Apr-98 6,800. 7,300. HIGH PRESSURE PERFORATING RECORD NWE1-02 TEMP CH 02-Apr-98 6,800. 7,480. TEMPERATURE LOG W/JEWELRY TIE - IN NWE1-02 RFT OH 21-Mar-98 3,027. 7,368. REPEAT FORMATION TESTER NWE1-02 PERF CH 03-Apr-98 6,750. 7,300. 2 1/2 PERFORATION RECORD NWE1-02 AlT TAPE 21-Mar-98 2,824. 7,574. PEX./AlT, DSI, FMI, CMR; MAIN AND REPEAT Please sign and return one copy of this transmittal letter. Thank-you, Nadene Reichert Petrotechnical Data Center ARCO - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil- Frank Banar Phillips- Paul Robertson DNR - Tim Ryherai Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 4/27/98 Trans# 89000 NWEILEEN DIRECTIONAL DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4944. DIRECTIONAL SURVEY Sw Name Type Date Co Comments NWE1-01 MS 03/04/98 SCH MAGNETIC MULTI-SHOT SURVEY W/DISC NWE1-01A MS 03/07/98 SCH MAGNETIC MULTI-SHOT SURVEY W/DISC NWE1-02 MS 03/21/98 SCH MAGNETIC MULTI-SHOT SURVEY W/DISC Please sign and return one copy of this transmittal letter. Than!~-you, .... ~,, / /~ Ga~ B Preble Petrotechnical Data Center STATE REPORTS DIRECTIONAL ARCO -G. Van Kooten DNR - T. Ryherd EXXON-C. Riley Phillips- P. Robertson Chevron- G.Forstaff Mobil- F. Banar ARCO -G. Van Kooten DNR - T. Ryherd EXXON-C. Riley Phillips- P. Robertson Chevron- G. Forstaff Mobil- F. Banar A~GCC- H. Okland Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 4/27198 Trans# 89048 NWEILEEN DIRECTIONAL DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4944. DIRECTIONAL SURVEY sw Name Type Date Co Comments NWE1-02 MS 04/03/98!GYRODATA GYRO CONTINUOS MULTISHOT SURVEY INSIDE 3.5" TUBING W/DISK Please sign and return one copy of this transmittal letter. Thank-you, ...... //~. /" ) . ., ~ :... x:.,.! L Gary B Pfeble Petrotechnical Data Center STATE REPORTS DIRECTIONAL ARCO -G. Van Kooten DNR - T. Ryherd EXXON-C. Riley Phillips- P. Robertson Chevron- G.Forstaff Mobil- F. Banar ARCO -G. Van Kooten DNR - T. Ryherd EXXON-C. Riley Phillips- P. Roberts~ Chevron- G. Forstaff Mobil- F. Banar ~~,.:H' Okland Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 Core Laboratories - Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Number of Samples: 5/ 5. ~" ~ / ~__c:. / Contact: ~,~,'~- ~'~- ~ /.~ .~ 3 Description of Material: Core Chip Samples Depths: Sent By: Received By: ~PR 17 ~98 05:09PM P.1/3 [FAX TO: Fax Phone TO: Fax Phone TO: Fax Phone TO: Fax Phone TO: Fax Phone Mike Martin - BP Prudhoe 7~621~0e~ ~l~ ~ Blair Wondzell - AOGCC 276-7542 Bill Smalstig - ~4rco 265-2535 I CC: RE~~$: [-] Urgent [~] For your review FROM: Phone Fax Phone Steve Deckert BP Exploration (,4laska) lnc 900 E. Benson Blvd Anchorage, AK, 99519-6612 DECKERSL~_~BP. COM 907-564-4128 907-564-5530 Date 4/17/98 INumber of pages including cover sheet [~ ReplydSAP ~] PleaseComment Attached is the "Shut-Down of Operations" Procedure that Mike Martin and I worked up. Blair Wondzell with the AOGCC gave me verbal approval for the procedure. We have permission to shut-down the operations for 1 year. If we have not restarted operations in 1 year, then we must review with the AOGCC and request an extension, ~PR ~? ~98 05:09P~ P~2/3 North West Eileen 1-02 Confidential Well Shut-Down Of Operations: Procedure OVERVIEW The North West Eileen 1-02 was drilled as a Kupamk C exploratory test to a total depth of 7583'MD. Core and log evaluation ,,vas completed on the well and it was decided to production test the well. 7", 26#/fl, L-80 casing set at 7575' MD and cemented in two stages. 3-I/2", 9.3 g/it, L-80 tubing was run to 6896' MD with a packer set at 6858' MD. The Kupanfl~ C1 was perf from 7168 - 7188' MD and frac'd. The Kupamk C3 was peff from 7079.5 - 7085.5' MD and frac'd. Currently attempts are being made to flowback the frac fluid and begin a production test. Ice pad conditions may not allow a complete production test. The following outlines the procedure for Shut-Down of Operations of the well pending return to testing or production within 1 year. CURRENT CONDITIONS Wellhead: Tubing: Cased Hole Interval: Pert"d Interval: Existing Wellbore Fluid: Standard PBU Tree with SSV. 6896 - 0'. 3-1/2", 9.3 g/tt, L-80. 7575'MD - 0'; 7" 26#/ft L-80 Butt-Mod. Cemented with 50 Bbl through shoe. Cemented with 85 Bbl through DV tool ~ 4822' MD. Downsqueezed 9-5/8" x 7" annulus with 51 Bbb. 7168 - 7188' MD& 7079.5 - 7085.5' MD. Frac fluid and/or produced oil and gas. PROCEDURE: 1. Complete well production testing operations as allowed by ice conditions. 2. Circulate with warm seawater down inner annulus through GLM back up tubing. Freeze protect top 2000' of tubing and inner annulus with diesel. 3. Dummy offGLMs. Install "XXN' plug at 6884' MD. Install "XX" plug at 499' MD. 4. Close in surface valves. RI)MO. Clean location Steve Deckert - BPXA Staff Engineer suo!lP. UaClO ~0 uMocI lnqs OqS 86/Z ' u°'qeldUJ°O le!l!Ul 1~ 86/BZCRO j pol~ EI/'¢ s48 '08-"1 '1¢h~9~ ',,/_ ~ )ueddoJd neJ-t us, fo uedo ~'§80Z - g'6ZOZ t~ ,Z/~-~ p,oeJ..-I uedo 1~8 L)_ - 89tZ e _ 9¢LLVI9 IYAaDLNI _-IDS (xx/xx/xx) ~lO/OHliit :90-1 X~-em uJh$ uo!~eJoj~ed ,E:'9~ = ^el3 Peal , I.'~lz= ^el3 '10 ,ff'O9= AeFi ,E'ZZ= ~el~! IleM iep, uepuuo0 luauJe3 slqB q]!~ JellOO 06e19 6Up, UeLUe: !sd 000'9 ',,8/_e,-g ~ 'OIAI_-i :PeeLIIleAA ,,OVO,, 'Je~te~i :JO,~erl)~Ov !sd 000'9 ',,gUL-t, 'MIO :aeJl ~/~'d--- Nd60:SO 86, ZT ~dU ,- BP EXPLORATION, Alaska Date: 04-07-98 Trans# 89007 NW EILEEN Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907)564-4944. dT~"~ '- O "~"C:~- Sw Name Log Type Rec Date Meas Depth Top Meas Depth Base Comments NWE1-02 MUDLOG 09-Mar-98 110. 7,583.1 ENGINEERING LOG NWEI-02 MUDLOG 09-Mar-98 110. 7,583. COMBINATION MUD LOG NWEI-02 MUDLOG 31-Mar-98 110. 7,583. ASCII FORMAT OF DB JO, CG, SU, CO, RE, GC, LI, LA, LO, MU, GE, BI Please sign and return one copy of this transmittal letter. Thank-you, Nadene Reichert Petrotechnical Data Center ARCO - Gerry Van Kooten Chevron - Garry Forstaff EXXON - Cheyenne Riley Mobil - Frank Banar Phillips- Paul Robertson DNR - Tim Rhyherd AOGCC - Howard Oakland PBU Satellites - Alistair Bent Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 3/25198 Trans# 88960 NWEILEEN STATE REPORTS NWEILEEN DIRECTIONAL DATA Enclosed is the materials listed below, if you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4944. STATE REPORTS Name Type Date Co. Comments NWE1-01A PD 03/18198 BPX PERMIT TO REDRILL/EXPLORATORY ] DIRECTIONAL SURVEY Name Type NWE1-02 MS Date Co. Comments 03111/98 SPERRY MAGNETIC MULTI-SHOT W/DISK Please sign and return one copy of this transmittal letter. Thank-you, , David B Ward Petrotechnical Data Center STATE REPORTS ARCO -G. Van Kooten DNR - T. Ryherd EXXON-C. Riley Phillips- P. Robertson Chevron- G. Forstaff Mobil- F. Banar DIRECTIONAL ARCO -G. Van Kooten DNR - T. Ryherd EXXON-C. Riley Phillips- P. Robertson Chevron- G. Forstaff Mobil- F. Banar AOGCC- H. Okland Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 MEMORANDUM State of Alaska TO: Alaska Oil and Gas Conservation Commission THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: John H. Spauldinc~,//,~+~ SUBJECT: Petroleum Inspect/fir // DATE: March 1 2, 1 998 agnlclfe.doc Confidential' Yes _, NoX, Attachment Only... . BOPE Test Nabors 18E BPX Wildcat (NWE 1-02) PTD 98-032 Thursday, March 12, 1998: I traveled to BPX's North West Eileen exploration well 1-02 to witness the BOPE test on Nabors 18E. As the attached AOGCC BOPE Test report indicates there were no failures. found the location and drilling rig in good condition. The drilling crew was knowledgeable about their equipment as well as the proper test procedure. SUMMARY: I witnessed the successful BOPE test at BPX's NEW well 1-02, Nabors 18E. 24 Valves Tested 3 Test Hours ~5 ~~t~P-~ , , -- Attachment:agnlclfe.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors Operator: BPX Well Name: N. W. Eileen 1-02 Casing Size: 9 5/8" Set @ Test: Initia X Weekly Rig No. 18E PTD# Rep.: Rig Rep.: 2827' Location: Sec. Other DATE: 3/12/98 98-032 Rig Ph.# 659-4608 G.W. Craig Allan Mikkelson 34 T. 12N R. 11E Meridian Umait TEST DATA MISC. INSPECTIONS: Location Gen.' ok Housekeeping: ok PTD On Location yes Standing Order Posted (Gen) yes Well Sign ok Drl. Rig ok Hazard Sec. yes FLOOR SAFETY VALVES' Upper Kelly / IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/5,000 P f 250/5,000 P I 250/5, 000 P I 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 250/2500 1 250/5,000 I 250/5,000 1 250/5,000 1 250/5,000 2 250/5,000 1 250/5,000 na 250/5,000 P/F P P P P P P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok CHOKE MANIFOLD: No. Valv.es 16 No. Flanges Manual Chokes Hydraulic Chokes 1 Test Pressure P/F 250/5,000 P 42 250/5,000 P 2 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 @ 1800 avg. 2,950 P 1,500 P minutes 29 sec. minutes 59 sec. X Remote: X Psig. Number of Failures: 0 24 Repair or Replacement of Failed Equipment will be made within 0 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS' Di st ri buti on: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: A9nlclfe.xls ,To/~n N. 5pouldin~ TONY KNOWLES, GOVERNOR ALASK& OIL ~ GAS CONSERVATION CO~DIISSION 3301 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: i907) 276-7542 February 25. 1998 James Smith Engineering Supervisor BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Rc' Pmdhoc Bay Unit NWE 1-02 BP Exploration (Alaska) lilc. Permit No. 98-32 Sur. Loc. 2513'NSL. 3918'WEL. Sec. 34. TI2N. R11E. UM Btmholc Loc. 46_8 NSL. 1935'WEL. Sec. 34. TI2N. R11E. UM Dear Mr. Smith: Enclosed is thc approved application for permit to drill thc above rcfcrcnccd xvcll. Thc pcrmit to drill docs not cxcmpt you fron~ obtaining additional permits required by law from other governmental agcncics, and docs not authorize conducting drilling operations u-ntil all other required pcrmitting determinations arc made. A weekly status report is rcquircd from thc time the well is spudded until it is suspended or plugged and abandoned. Thc rcport should bca gcncralizcd synopsis of thc xvcck's activities and is cxclusivclv for thc Commission's internal usc. Blowout prevention cquipmcnt (BOPE) must bc tested in accordancc with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test pcrformcd before drilling below thc surface casing shoc must be given so that a representative of thc Commission may witness thc . test. Notice may be givcn by contacting thc Commission pctrolcum ficld inspcctor on thc North Slope pager at 659-3607. BY ORDER OF MISSION dlffEnclosures Department of Fish &Gamc. Habitat Section xv/o cncl. Department of Environmental Conscr~'ation w/o cncl. STATE OF ALASKA. AL .JKA ~,,L AND GAS CONSERVATIC.. cOM,vllSSION PERMIT TO DRILL 20 AAC 25.005 CONFIDEN, AL la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 29' Prudhoe Bay Field / Kuparuk 3. Address 6. Property Designation River Oil Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028239 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2513' NSL, 3918' WEL, SEC. 34, T12N, R11E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 4658' NSL, 1935' WEL, SEC. 34, T12N, R11E, UM NWE 1-02 At total depth 9. Approximate spud date Amount $200,000.00 4658' NSL, 1935' WEL, SEC. 34, T12N, R11 E, UM 03/01/98 '~' 2. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD'and TVD) ADL 028238, 1935'I No Close Ap.p..(o. ach 2560 7747' MD / 7050' TVDss 16. TO be completed for deviated Wells .... 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} ' ' Kick Off Depth 400' Maximum Hole Angle 29-2° Maximum surface 3342 psig, At total depth (TVD) 6442' / 3986 psig 18. Casing Program Setting Depth Size Specifications ....... Top Bottom ..Quan.tity of Cement Hole Cedi'rig Weight G'rade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arctic Set (Approx.) , _12-1/4;" 9-5/8" 40# L-80 '"BTc 2860' '"'""Surface Surface 2860' 2600' 382 sx 'G', 1175 sx PF, 82 sx 'G' 8-1/2" 7" 26# L-80 BTC-M 7747' Surface Surface 7747' 7050' 287 sx 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 M D TVD Structural Conductor S u rface ,;';i~ ..... Intermediate ,,'~ ~< - P re d u c tic n .,'. ~' '?"' .~!? 'i:/" ,~: , ,,., : :,, , .. Liner ,~¢:,. ~'~.,'o, "..' ,, ,'~ ..~'~' '~ ,, ~,,, ~,,,~ ' t",/.~ ,I ' ," ,. ~'~'" ORIGINAL Perforation depth: measured true vertical .... ,.., ......... ~ .......... ~,~_.._.......~.~ ............ 20. Attachments ~ Filing Fee ~ Prope~y Plat ~ BOP Sketch ~ Dive,er Sketch ~ Drilling Program ~ Drilling Fluid Program ~Time vs Depth Pict ~ Refraction Analysis ~ Seabed Repo~ ~ 20 AAC 25.050 Requirements ......... Contact Engineer Name/Number: Preston Evans, 564-5540 Greg West, 564-4803 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby Certif~ that the foregoin¢ true and correct to the best of my knowledge Signed Jame~~2(;~ ~ ~'-- Title Engineering Supervisor Date ........ Commission Use Only Permit Number I APINumber I ApprovalDate [ See cover letter ~-~ ~ 50-O ~ ~ ~ ~ ~~ ~~'~ for other requirements Conditions of Approval: Samples Required ~Yes ~ No Mud Log Required[ ~Yes ~ No Hydrogen Sulfide Measures ~Yes ~ No Directional Survey Required ~Yes~ No Required Working Pressure for BOPE ~2M; ~3M; ~5M; ~ 10M' ~ 15M Other: ()rigiRa~ SigRed 8y by order of ~/, _. ~,...> .~pproved By (;"2',V~'~ W..~ohngtOR Commissioner the commission Date Form 10-401 Rev. 12-01-85 Subm~ plicate I We,, Name: I NWE 1-02 Well Plan Summary Type of Well (producer or injector): I Appraisal Producer I Surface Location: 2513' FSL, 3918' FEL, T12N, R11 E, S34 * As staked X = 582996, Y = 5978232 Target Location: 4658' FSL, 1935' FEL, T12N, R11E, S34 X = 584730 Y = 5980140 Bottom Hole Location: 4658' FSL, 1935' FEL, T12N, R11 E, S34 X = 584730 Y = 5980140 I AFE Number: I 4P1037 I Estimated Start Date: 13/1/98 MD: 7747' I Rig: I Nabors18-E TVD: Operating days to complete: 7050'ss IRKB/ ~Surface I Elevation I (a.m.s,I) 120 Well Design (conventional, slimhole, etc.): Conventional ultra-slimhole "S" Shaped - If overpressuring is found in the Kuparuk from NWE 1-01, well design will shift to conventional big bore. IObjective: I 4" core the Kuparuk C sand Evaluate Reservoir Quality and Hydrocarbon presence in the Kuparuk reservoir, obtain a I CONFIDENTIAL Formation Markers Formation Tops MD TVD (SS) Ultra-Slimhole Design Big Bore Contingency 400 324 KOP-Begin build 1809 1683 End Build, hold 42° Base Permafrost 1828 1700 Based on offset West Kup & NWE State #1 T-3 2573 2350 2860 2600 Surface casing point in Surface casing point shale, 9-5/8" 40# L-80 in shale, 13-3/8" 68# Surface casing below L-80(if over- the hydrate zone and pressuring found in above the potential the Kuparuk on NWE hydrocarbon zone - 1-01) Ugnu. K-15 (Ugnu) 2911 2645 May have slight overpressure from gas injection at GC2 Actual pore pressure will be measured in NWE 1-01 and information used in 1- 02 accordingly(est. 9.0- 9.2ppg EMW) K-13 (West Sak / 4716 4220 Schrader) K- 12 4969 4440 K- 10 5490 4895 5964 5308 Begin Drop 3°/100 K-5 6172 5495 K-2 6757 6060 6939 6242 End drop 7000 6300 Top set casing shoe for 9-5/8" 40# L-80 (if overpressuring is found in the Kuparuk in NWE 1-01) K-1 (Kuparuk D) 7107 6410 Cap rock for the Kuparuk reservoir Kuparuk C 7139 6442 Primary Target - Pore pressure will be determined from RFTs in NWE 1-01. Offset data indicates a worst case pore pressure of 11.9 ppg EMW. Will core this interval Kuparuk B (LCU) 7265 6568 Kuparuk A 7430 6733 Miluveach 7512 6815 TD 7747 7050 Casing point, 7" 26# L- Casing point, 7" 26# 80 in the Miluveach L-80 in the Miluveach formation, formation. CONFIDENTIAL Casin¢/Tubinq P oq am Ultm-$1imhole Design Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDFTVDss 30" 20" 91.5# H40 WELD 80' surface 80'/80' 12-1/4" 9-5/8" 40# L-80 BTC 2860' surface 2860'/2600' 8-1/2" 7" 26# L-80 BTCM 7747' surface 7747'/7050' Tubing 3-1/2" 12.6# L-80 8RD EUE 7039' surface 7039'/6312' Big Bore Contingency HJle Size (~sg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVDss 30" 20" 91.5# H40 WELD 80' surface 80'/80' 16" 13-3/8" 68# L-80 BTC 2860' surface 2860'/2600' 12-1/4" 9-5/8" 40# L-80 BTC 7000' s u rface 7000'/6300' 8-1/2" 7" 26# L-80 BTCM 7747' surface 7747'/7050' Tubing 3-1/2" 12.6# L-80 8RD EUE 7039' surface 7039'/6312' General Mud Program: Ultra-Slimhole w/7" Longstring Surface Mud Properties: Fresh water 12-1/4" hole section Adjusted as bentonite spud mud necessary from NWE 1-01 Density Marsh Yield 10 sec 10 min pH APl (PPG) Viscosity Point gel gel Filtrate 8.6 300 15 8 10 9 8-15 to 10.2 <150 35 15 30 10 8-15 Intermediate Mud Properties: Fresh Water 8-1/2" hole section - Adjusted as LSND necessary from NWE 1-01 Density Viscosity Yield 10 sec 10 min APl HTH P (PPG) Point gel gel Filtrate Filtrate Initial LSND 8.6 35-40 6-8 3-6 7-10 6-12 NA Final LSND 9.5 40-45 10-20 6-10 15-20 4-6 10-12 Production Mud Properties: Bland, Non- Invasive coring Fluid will be used in coring Kuparuk. Once core point has been picked, procedure will be open hole mud displacement. Formulation Water Bentonite Biocide (Aldacide G) Drispac SL Starch (Dextrid) XCD KCI Calcium Carb. (5 micron) Deuterium Oxide Tracer Barite I I 8-1/2" hole section O.87 bbl 7-8 ppb 0.5 ppb 1.75 ppb 7-8 ppb 0.25 ppb 6% 60+ ppb 850 ppm (added) as needed I I TONY KNOWLE$. GOVEBNOt~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januarx 23. 1998 John R. Denis PBU New Business Dcvclopmcnl BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Subject: PBU NW Eilccn Appraisal Wells - Surface Commingling of Test Production from Wells NWE 14)1. 1-02. 14)3 and 2-01 Dear Mr. Denis: The Commission received your lctlcr dated Januan' 14. 1998. requesting permission lo commingle Kupamk Pool production from the Kuparuk formation with 1PA production from thc Prudhoc Pool during lest operations. Your rcqucsl is for surfi]cc commingling onh' and that there will be no doxvnholc commingling of formation fluids from thc formations comprising the Pmdhoe Pool. Production from NWE 1-01. 1-()2. 1-()3 and 2-0 i should bc rcportcd scparatcly lo thc Prudhoc Bav Field. Kupamk River Pool (CO 98A. pool nmnbcr 640140) during thc test period. Production from N~,~E 2-01 Sag/h'ishak formations should bc rcportcd lo thc Pmdhoc Pool (pool number 640150) for those months the well is on test. Attached is a summar,,' of thc standard allocation procedures for commingling fluids from separate pools. These procedures have been developed over the last several ,,'cars and can serve as a guideline for allocating thc fluids from thc test operalions. Disregard paragraph (c). regarding NGL allocation, until such time the wells arc placed ou regular production. A minimum of m'o tests per month is required during those months Ihe xvclls arc produced. We look forward to hearing rcsults of thc Icst. If thcrc an)' qucstions regarding commingling or reporting procedures, contact Jack Hartz at 279-1433 ext. 232. Alaska Oil & Gas Co~n Commission '"" Attachment K. Boyd. DNR/DOG J. Pilkinton. DOR NWEconun.doc i~rociuci~Oti froi~l otilcr Doois for Droccss;[lu :It PBU (5(.' ~C~ICIIIIICS DFIOF ICL ,2llslodv Irnnsl'cr. Conduct x~cl} tcsls to determine production rates for c:~ci~ (.'alculatc each xxctl's theoretical monlhlv producl~on ('I-MP) based on well lest rate(s) and '~¢tual time on production. ~ii. Sum thc TNlP volmnc For all xxctls in all pools. Determine an allocation t'nctor as lhe rzttlo of thc mclcrcd x'olumc to Ibc TMP For all wells pools (i.e.. ~nctcrcci/¥.x, lP'~ x'. Calculate each well's actual monthly production (AMP) ,.'olumc AMP = TMP x Allocation Factor NGL's xvill be allocated to each pool based on actual gas production volumes and NGL process simulations. Process simulations will be updated at least once per year based on NGL samples and results reported ~o the Colllmi$sion. teach producing xx'cll xxill be tested at least twice each month. Wells that have been shut in and cannot meet thc txvicc-monthlv test frequency must be lcslcd within five days of stanup. All available lest separator capacity within lhe constraints imposed by operating conditions must be utilized lbr well testing. ©ptimum lest durmion and stabilization t,me xvill be determined on a xxctl by x,,'cll basis by the <)pcr:llor. Water volumes will be dclcrnllncd by API/MPMS approved methods, or the usc of industry proven on-line water cut measurement devices approved by thc Commission. APl grax'itv will be determined for each producing well a,'muallv by an API/MPMS approved method. h, Gas samplcs x~'ill bctakcn and anatvzcd for composition from each non=,,as lifted producing well yearly. CONFIDENTIAL Density Viscosity Yield 10 sec 10 min pH APl HTHP (PPG) Point gel gel Filtrate Filtrate 10.6* ALAP 20-30 4-8 8-12 7.5-8.5 <4.0 <8.0 *Density adjusted accordingly for slightly pressured Kuparuk, will change from results of NWE 1-01 RFT in formation. Directional KOP: Maximum Hole Angle: Close Approach Well: +400' MD (estimated) _+29.2° None Cement: Ultra-Slimhole w/7" Lonqstrinq First Stage Second Stage Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments 9-5/8" surface Class "G" tail' Permafrost Lead' Two Stage Job: 382/15.8/1.15 1175/12.2/1.92 First stage calculated as Class "G" tail from TD to the ES cementer at 2028'md @50% excess Class "G" tail' Second stage calculated as a class "G" tail 82/15.8/1.15 tack from 2028'-1900'md @50% excess and then Permafrost cement circulated to surface assuming 300% excess. Lead Tail Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments 7" Intermediate 287/15.8/1.15 Class "G" Tail, Top 1000' above Kuparuk, 50% excess Logging Program LWD Logging: 12-1/4" Hole MWD directional, Mug Logging 8-1/2" Hole MWD directional/GR / Res, Mud Logging Open Hole Logs (eline): 12-1/4" Hole 8-1/2" Hole Cased Hole Logs (eline): No Logs needed 1) Platform Express (GR/RES/Den/NUE) 2) Dipole Sonic 3) Optional Percussion SWC if hydrocarbons are encountered 4) CMR 5) FMI 1) USIT/GR 2) GCT gyro 4- Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics for Nabors 18E are on file with the AOGCC The Kuparuk reservoir will be drilled with pore pressure knowledge from NWE 1-01, there is a possibility of abnormal pore pressure of 0.62 psi/ft or 11.9 ppg EMW. Maximum anticipated bottom hole pressure is 3986 psi at 6442'TVDss. Maximum anticipated surface pressure assuming gas in entire annulus (0.1ppg) is 3342 psi. Hazards · Ugnu may be slightly overpressured due to water disposal at GC-2 which is 10.5 miles to the east. (Again, pressure will be determined from RFTs in NWE 1-01) · The well path will cross one major fault with about 200' of down throw. This fault will be discussed within the well plan and measures will be taken to control lost circulation or other problems associated with drilling across the faults. · Based on offset well data, there are known accumulations of frozen gas hydrates in the area. Will apply NWE 1-01 knowledge to treat as necessary. (See attached discussion). _. The Kuparuk C Sand is potentially overpressured due to gas injection in the Kuparuk Operating Unit.'~ Recent well data suggests that a pore pressure of 0.62 psi/ft is possible. RFTs from NWE1-01 will show more accurate data. Disposal Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal. NWE 1-02 Short Well Summary Rig 1. MIRU. NU diverter and function test same. 2. Drill 12-1/4" hole directionally (KOP @ 400' md) with MWD Directional to -2860'MD/2600'TVDss below the in the SV1 interval. Run and cement 9-5/8" 40# L-80 casing to surface with Halliburton ES cementer (two stage surface cement job). 3. ND diverter, Install Blow out prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Test BOPE to 250/5000 psi. 4. RIH with PDC bit, Test 9-5/8" casing to 3000 psi for 30 minutes. Drill out float equipment and shoe and 20' of new formation; perform a formation leak-off test using the BJ cement unit as per the SSD Leak off Test Procedure - expect ~12.5 ppg EMW test. (Will know more from LOT data in NWE 1-01) 5. Drill 8-1/2" hole tangent with MWD/GR/RES to -5964'md and then drop at 3°/100 in order to line up vertically prior to reaching the Kuparuk reservoir. Assuming Iongstring scenario (ie. Normal pressures in Kuparuk C), rig will drill to core point in the Kuparuk D sands. 6. Will core 8-1/2" hole (4" core) to obtain 120 feet of Kuparuk C sands. 7. Drill 8-1/2" hole with MWD/GR/RES to TD of 7747' md which is below the top of Miluveach in order to provide adequate rat hole for logging tools. 8. Run platform express logs on eline (GR/RES/Den/NEU). 9. Run DIPOLE SONIC on eline. 10. Run CMR logs on eline. 11. Run FMI on eline. 12. Plan to run SWC if hydrocarbons are observed in the Ugnu while drilling the intermediate hole section. 13. Make a clean out bit run to TD and prepare for running casing. CONFIDENTIAL 14. Run and cement 7" 26# L-80 casing to surface and cement with Class "G" cement to 1000' above the Kuparuk D interval. Bump the plug with 3500 psig, check the floats. 15. Run 3-1/2" 9.3# L-80 tubing completion and set a 3-1/2"x7" production packer -100' above production zone. 16. Test tubing and annulus. Set TWC. 17. ND BOP, NU and test tree. 18. Pull TWC, freeze protect, set BPV, RDMO. 19. Well will be tested by PE group following rig release. Big Bore Contingency IF 11.9ppg EMW pressures are found from RFT data in NWE 1-01 for the Kuparuk C interval, the casing design will change to big bore. 1. Drill 16" surface hole and set 13-3/8" 68# L-80. 2. Test casing, drill out and perform LOT. 3. Drill 12-1/4" hole tangent to 100' md above the Kuparuk D interval. 4. Set 9-5/8" 40# L-80 casing. Test casing. Drill out and perform LOT. 5. Drill 8-1/2" hole to core point and core Kuparuk C sands (4" core). 6. Drill 8-1/2" hole to TD. Log, complete and test as stated above. CONFiDENTIaL PROPOSED DRILLING PROGRAM WELL: North West Eileen 1-02 (NWE 1-02) Ice pad construction is complete and Nabors 18E is already on location from NWE 1-01 operations. Again, the rig will be placed on rig mats and herculite. Drilling Operations: (All depths are approximate) The ice pad is constructed and the well cellar excavated. The conductor hole is be pre-drilled and a 20" conductor is set. Move in, rig up. Accept rig for operations. Nipple up diverter and function test same. The well will be drilled as a S-shape wellbore. The 12-1/4" hole section will be directionally drilled from 400'md and will contain a gradual build section in order to line out to a ~29° tangent angle at the surface casing point at 2860' MD. Run and cement 9-5/8", 40# casing to surface utilizing a two-stage cementing equipment. (This plan is based on the absense of overpressure found in the Kuparuk C sands from RFTs run in NW Eileen 1-01 .) Install blowout prevention equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and 5,000psi annular preventer. Test BOP's. Maximum anticipated possible reservoir pressure is 3986 psi (11.9 ppg EMW) at 6442' TVDss. Pore Pressure will be confirmed during logging of NW Eileen 1-01. Actual anticipated pressure in the Kuparuk C sand is on the order of 9.8-10.7 ppg. Maximum possible surface pressure is 3342 psi based on a gas column to surface from 6442' TVDss. Mud logging facilities and operations will be on location and functional from spud to TD of the well. A formation leak-off test will be performed 20' below the 9-5/8" casing shoe. If necessary, a formation integrity test will be performed prior to drilling into the Kuparuk D shale. The 8-1/2" hole section will be drilled tangent to ~5964'md and then will begin a 3°/100 drop section in order to position the well vertically before coring the Kuparuk C interval. The 8-1/2" intermediate section will be drilled to the base of the Kuparuk D shales and then the Kuparuk C sands will be cored. (Longstring Design). *** The pore pressure will be closely approximated before spud of this well. NWE 1-01 will take RFTs in the C sands. This information will determine whether a big bore design is needed. The Kuparuk C sand will be cored with a 8-1/2" barrel (4" core). The hole then will be drilled to TD. Side Wall Cores will be obtained if hydrocarbons are observed while drilling the Ugnu and Schraeder Bluff hole section. Run logs (platform express, dipole sonic, CMR, RFTs, FMI) on eline. Clean out hole. Run and cement 7", 26# L-80 casing bringing top of cement to 1000' above the top Kuparuk. Run 3-1/2" completion string. The well is planned to be tested by the PEs after the drilling rig is moved off of the well. The well is planned to be suspended with the completion string left in the wellbore. If the well is abandoned, the appropriate plugs and markers according to AOGCC regulations will be met. The pad will be cleaned up of any surface debris. North West Eileen 1-02 Pore Pressure / Fracture Gradients / Hazard Summary · Pore Pressure Review of seismic data in the vicinity of North West Eileen 1-02 (NWE 1-02) in conjunction with offset well records (mud logs, sonic logs) has indicated that no abnormal pressures are expected in the NWE 1-02 area aside from the Ugnu which has potentially been charged from produced water injection and the Kuparuk C sand interval which has potentially been overcharged from gas injection in the Kuparuk River Qperating Unit. The Ugnu sands are charged in many parts of Prudhoe Bay and the pore pressure is expected to be .--9.0-9.2 ppg in that interval. An abnormal pressure of 0.62 psi/ft or 11.9 ppg EMW is potential in the Kuparuk C sand interval due to gas injection. The over-pressure gradient originates from the Kuparuk River Unit gas injection strategy which originates at DS I-C. This overpressure was confirmed most recently in the 1 C-12 and 1C-13 well drilled by the Arco Kuparuk drilling group. The abnormal pore pressure may be baffled by two significant faults which are located to the west of the NWE 1-02 bottom hole location; however SSD will plan the well assuming the abnormal gradient mentioned above. Mud weights which provide 100-200 psi overbalance will be used to ensure hydrostatic control. The well is planned to TD at the top of the Miluveach or base Kuparuk. · Fracture Gradient Information available from the offset wells have been reviewed to provide a best estimate of fracture gradients to be expected. 9-5/8" casing point (-2600' TVDss) should provide a fracture gradient of 12.2 - 13.5 ppg EMW. This leak off result will provide sufficient kick tolerance to drill to planned TD of the 8-1/2" hole section in the Miluveach at ---7050'TVDss. · Kick tolerance monitoring and pore pressure determination techniques Kick tolerance volume will be continually updated as the well is in progress, incorporating the most up-to-date data available from the well. The real-time resistivity log incorporated in the MWD assembly will enhance the mud logging crew's ability to monitor for change in pore pressure in addition to the normal techniques of D-Exp. projections, cuttings quality, connection gases etc. CONFiDENTiAL Shallow Gas and Shallow Gas Hydrate Analysis Based on review of a seismic traverse line that includes analogue wells Arco NW Eileen St #1, Mobil West Kuparuk St #1, and Socal 33-29E, no shallow gas pockets are expected on the North West Eileen 1-02 well. No seismic anomalies were seen at any of the three analogue wells or at the proposed ice pad NWE 1. However, the North West Eileen area does not have any high resolution seismic and offset data will therefore be used as the primary source to evaluate potential drilling hazards which could include shallow gas and/or hydrates. Based on review of offset drilling data, the potential to encounter hydrates while drilling surface hole at NWE 1-02 is high. Review of off-set well data reveals presence of hydrates near the base of the permafrost. The offset wells reviewed include Mobil West Kuparuk State #1, NW Eileen State #1 & #2, West Sak 24, KRU 1C-12, Prudhoe Bay Z pad, and Milne Point K pad. When a hydrate zone is encountered, the relative warmth of the drilling mud will decompose the hydrates and gasify the mud. The hydrates adjacent to the wellbore will continue to decompose and gasify the drilling mud as long as drilling operations continue to introduce heat into the hydrate-bearing interval. While encountering shallow hydrates has been known to cause severe problems in other parts of the world, this occurrence is well known and handled frequently at Prudhoe Z-Pad and Milne Point. The use of high density mud weight (-10.2 ppg) and the additive Lecithin, are two proactive safety measures that will be employed in the drilling operation. Data from off-set wells shows gas hydrates to most likely exist at the base of the permafrost in several layers beginning at 1500' tvd to 2450' tvd with a total thickness of 171' to 349'. The base of the permafrost in NWE 1-02 is expected to be -1720' tvdss. Operating procedure will be to add Lecithin to the drilling fluid when gas cut mud is found by the mud logger. The mud weight will continually increase from 8.6 ppg at spud to 10.2 ppg at ~1600' tvd and remain so until surface hole TD. These actions continually prove to be sufficient when gas hydrates are encountered at Milne Point and Prudhoe Z-Pad. Nabors 18E will also be equipped with the following gas detection systems as a proactive measure to monitor shallow gas and/or hydrates: · Rig gas sensors located at the pits, cellar, & rig floor · PVT system · Trip tank · Well Mud Loggers - Specialized personnel - Total Hydrocarbon Analyzer (FID) - Gas Chromatogragh (FID) Usual SSD procedures will be followed to minimize any potential for a shallow gas kick. Sufficient hydrostatic column will always be maintained while drilling the well and the correct tripping procedures will be followed while tripping in and out of the hole. If a shallow gas kick is taken prior to setting surface casing, the gas kick will not be shut-in, but diverted through the diverter system. If you have any questions, please give me a call at 564-4803. C, ONF [ ENT AL North West Fileen 1-02 Anticipded Pore Pressure/Mud Weight/Fradure Gradient 1000 2OOO 5000 4000 5000 6000 7000 8OOO ppg EMW 8 9 10 11 12 15 14 15 / For Hydrates , ':": ~' ~/ · · 9-5/8" casing k · point · (2600'tvdss) t ~t Max 'rac Grad . ! PlannedVlud Weight - ~ ' Expected Por~, ! Pressure - ~ , - ~ , Ra se Mud Weight Fo Kuparuk-Overpressure ~ ! 7" casing point -- 1 I-- (7050'tvdss) Top Kuparuk D ~%'~"""'"'""'~"I'~'~'~~~'""'""'"'"'"' C 0 , Proposed NWl i-02 Wellbore ~F Elev = I'~t~'-- 5-1/2" SSS\/Lending N~pple ~s, ,,,xo,, I ~,ooo' I I-1/2",9.5 #/"fi, L-a0, EUE 8RD Tubing I Gas Lift Mandrels ~ I,'- Camco, KBG-2-LS, 1" Pocket i i TBA 9-5/a", 40tt/fL L L--ao, BUs [ 2a~O'md [--~ l Max Hole Angle = 29.2' @ 1809'md · II I' ~-~-1/2"' 'x': ~NLE(:; int,o Tieback ~ Jsleeve /s.~s" ~ Tie ~ack S~eeve _ ..___.~ ~. ~.~aker ~lklan~er Packer 7", 26#/ft, I 774-7'md I ~., · L-80, Btrs Mod Mud Weight Chart IYJlss__ _Formation MW ppg 1600 Permafrost 10.2 2785 Ugnu 9.,3- 6600 7" casing 12.2 Shoe/Kuparuk D Date Rev. By Comments 1/16/98 c Wed. Proposed Initial Completion WELL: NWE 1-Or APl No_:_5~-029- 228_5_8. BP Exploration (Alaska) Gas Lift Mandrels Camco, KBG-2-LS, 1" Pocket ~ M~ WDs_s TBA Mud Weight Chart IYJlss___Formation MW ppg 600 Permafrost 10.2 2785 Ugnu 9.3- 6600 7" casing 12.2 Shoe/Kuparuk D CONFi EiEN-i : ,,,, ANADRILL DPC P&GE 1 0 ' b , NWE #]-02 (P4) VERTICAL SECTION VIEW Section at: 42.89 TVO Scale.- ] inch = 800 feet Oep Scale.' ~ inch = 800 feet Bnawn ..... ' 06 Feb J998 Anadr'J.ll Schlumberger Narker rden[~f~catJon ND 8KB SECTN 'I'NCL~ Al KB 0 0 0 O. o0 B) KDP BUILD ]/iO0 ,400 40o 0 o.od c) BUILD `1.5/t00 600 600 3 2,00 0] BUILD 2/i00 800 BO0 i6 5.od E) BUtLO ,?..5/100 lO00 998 40 9.0~ F] END 2,5/`100 BUILD `18]0 ~759 304 29.24 G) 9-5/8" CSG PT <11> 2860 8676 817 29.241 H) DROP 3/~.00 5965 5385 8334 29.24 I] END 3/'100 DROP 6940 63`18 2577 J) TARGET 2J40 65J8 2577 o.ooi K) TB / 7" LNR PT <il> 7748 7t~6 2577 0,00 0 400 800 1200 '1600 2000 2400 2800 3200 3600 4000 4400 4800 ~ ?00 Section Depar~une ~ ANADRILL DPC PAGE 11 Manker Identification MO N/S E/W A] KB 0 0 N ~1 ~o~ ~u~o ~oo ~oo o ~ ~ ~ ~1 ~uz~ ~rtoo ~oo t~ ~ ~ ~1 ~uz~ ~.~z~oo ~ooo ~ ~ ~ ~ F) END 2.5/100 BUILD J810 223 N 207 E G) 9-5/8" CSG PT <it> 2860 599 N 556 E HI DROP 3/I00 5965 t7]0 N J58§ E I) END 3/~00 DROP 6940 1888 N 1754 E J] TARGET 7140 ~888 N ~754 E K] TD / 7" LNR PT <Il > 7748 1888 N ~754 E 150 0 150 300 450 600 <- NEST' EAST -> 75O 900 NWE #1-02 (P4) PLAN VIEW i CLOSURE ' 2577 feet at Azimuth 42.8! DECLINATION,' +27.859 (E) SCALE ' 1 inch = 300 feet DRAWN ' 06 Feb 1998 ii /lnadri ]l Schlumberger i! ii, 1050 '1200 1350 'J500 JB50 1800 Anadrill Schlumberger Alaska District 1Zll East 80th Avenue Anchorage, AK 99518 (907} 349-4511 Fax 344-2160 DIRECTIONAL ~ELL PL~g for SKARED SERVICES DRILLING Well ......... : Field ........ : Prudhoe Con,Duration..: Minimum Ck/rvature U~its ........ : FEET Surface Surface Losg.: Z49-3261{$99 Legal Description Surface ...... : 2513 FSL 3918 FEL S34 T12N RllE UM Target ....... : 4401 FSL 2168 FEL S3~ T12N RllE U~ R~IL .......... : 440~ F~L 2Z60 FEL 834 T12N RllE LT~ LOCATIO~S - ALASKA Zone: 4 X-Co, rd Y-Coord 582996.98 ~978232.69 584730.00 59801~0.00 58~730,00 5980140.00 STAT[ON MEASURED INCLi~ IDENTIFICATION DEPTH A/~GL~ AZI~UI~{ ~ 0.00 0.00 O.O0 KO~ BUI~ 1/300 ~O0.O0 0.00 42.89 5~0.00 Z.00 42.89 ~UILD ~.5/100 600.00 2.00 42.89 7OO.00 3,50 BUILD 2/I00 PROPOS~D WELL PROFILE VER~ZCAL-DE~'i"KS $~CTTO~ T%r~ SUB-SEA DEPART 0.00 -75.80 0.00 400.00 324.20 ~.0O ~99.99 424.19 0.87 599.96 524.16 3-49 699.84 624.04 8-29 BUILD 2.5/100 Prepared ..... : 06 Feb 1998 Vert sect az.: 42.89 KB elevation.: 75.80 ft Magnetic ~cln: +27.859 Scale Factor.: 0.99990783 Convergence..~ ~0.6346141~ ANA~-q~L.L AKA-DPC FEASIBILITY PLAN I NOT APPROVED FOR EXECUTION PLAN #._{/ _ COORDrNA~S-FRO~ AJ~ASKA Zone 4 TOOL DL/ ~ELLHEAD X Y FACE ==~==~= =~= ==~== __ 0.80 N O.O0 E 5~2996.98 597~232.69 43R 0.00 O.O0 ~ O.O0 E 582996.98 5978232.69 43R O,OO 0.~4 ~ 0.59 E 582997.57 5978233.34 43R 1.O0 2.56 N 2.38 E 582999.33 597823~.27 43R 1.80 6.07 N 5.64 E $83002.$5 5978238.82 43R L.50 800.00 5.00 42-89 799.56 723.76 15.70 L1.50 N 10.69 E 583007_54 5978244.31 43R 1.50 900.00 7.00 42.89 899.01 823.21 26.15 [9.L6 ~ 17.80 ~ 583014.56 5978252.84 ~S 2.00 10O0.00 9.00 ~2.89 998.03 922.23 40.07 29.35 N 27.27 E 583023.92 5978262.34 HS 2.00 ILO0.00 ti. S0 42.89 /096.43 1020.63 57.86 42.39 N 39.30 E ~$3035.89 5978275.5l HS 2.50 120O.0O 14.00 42.89 1193.96 1118.]6 79.93 58.56 N 54.40 E 583050.73 5978293.~4 ~S 2.50 1300.00 16.50 42.89 1290.43 12~4.63 106.23 77.83 N 72.3D E 583068.4[ 5978311.30 HB 2.50 1400.0Q 19.00 42.89 1385.66 1309.~6 136.71 1GO.16 N 93.05 S 5§3088.9L 5978333.86 HS 2.50 rtl Z Z H 06 Feb 1998 Pa~e 2 PROPOSED WELL PROFILE STATION IDfi~~TI FICA?ION 2.5/700 BOrLD RASE PERMAFROST 9-5/s- CSG PT K-25 K- 13 SCHRADER K-12 K-10 DROP 3/100 E-2 MEASURED DEPTH ~500.00 1600.00 1700.00 lB00.00 2809_7~ I~CLN D[REOTION VERTICAL-~EPTHS SECTION Ai~GE AZ I~[FfH ~VD SUB-SEA DEPART 21.50 42.89 1479.47 1403.67 171.32 24.00 42_89 1571.68 3495.88 209.99 26.50 42.89 1662.1~ 1586.32 252.64 29.00 42,$9 1750.61 L674.81 299_20 29.24 42.89 1759 . 32 16~3.39 3 03.9t 1828.85 29.24 42.89 L775.80 3700,00 313.28 2573.80 29.24 i2.89 2425.80 2350.00 677.20 2860.~1 29.24 i2.~9 26~5.80 2600.00 827.17 2911.a9 29_24 42.89 2720.80 2645.8U 842.37 4716.94 29_2~ 42.89 4295.80 4220.00 1724.18 4969.07 29.24 42.89 4525.80 4440.00 2847.35 5490.53 29.24 42.$9 4970.80 4895.00 2202.09 5964.99 29.24 42,89 5384.79 53D8.99 2333.88 6000.00 28.19 42.89 5415.49 ~339-69 2350.70 6100.00 2~.19 42.89 550~.8~ 5429.02 2395.62 6272.29 23.02 i2.~9 5570.80 5495.00 2t25.14 6200.00 22.19 42.89 5596.38 5520.58 2435.80 6300.00 19.L9 42.89 5689.92 5614.12 2471.13 6~00.00 26.L9 42.89 5785.L8 5709,38 2S0L.52 6500.00 23.19 42,89 ~8~1.90 5806,10 2526.88 =______ COORDItlATHS-FRO~ ALASKA Zone 4 TOOL DL/ WBLLHEAD X Y FACE 100 125.51 ~ 116.61 E 563112,18 5998359.48 HS 2.50 163.84 N 142.93 E 583138.18 5978388.09 HS 2.50 185.09 N ~71.96 E 583166.86 5978429.66 HS 2.50 219.20 N 203.65 E 583198.17 597845~,11 HS 2.50 222.67 N 206.$8 E 583201.36 5978457.62 H8 2.50 229.5~ N 213.23 E $~3207.64 5978{64.53 H$ 0.00 496~13 N ~60.93 E 583452,34 $978733.85 HS 0.00 598,68 ~ 556.20 E 583546.46 597~837.43 627.13 N 573.35 E 583563.~0 597~856.08 HS 0.00 1263.26 N 1173.54 E 584156.35 5~79508.66 HS 0.00 1353.40 ~ 2257.38 E 584239,17 S979599.82 HS 0.00 2540.04 N 2430.77 E 584410.4~ 5979788.33 US 0.00 1709.g~ N 1588.53 E 584566.33 5979959.87 LS 0,00 1722.17 ~ 1599.98 E 584577.64 59~9972.31 LS 3.00 1755.88 ~ 1630.55 ~ $846~7.84 5980005.55 L~ 3.00 1776.71 N 2650.64 E 58462?.69 5980027~40 LS 3,00 ~784.51 N 1657.90 E 58~634.86 5980035,29 LS 3.00 1~30.40 ~ [681.94 E 5846S8.62 5980063.44 LS 3-00 1~32.66 ~ 1702.63 E 5846~9.05 5~80083.93 LS 3-00 1851.24 N 1719.89 E 554696.10 S980102.69 LS 3-00 6600.00 10.19 42.89 5979.81 5904.02 2547.1~ 2866,09 6700.00 7,~9 42.89 6078.65 6002.85 ~56~.26 1877~26 6757.50 5,~7 42.89 6135.80 6060,00 25~8.60 1881.80 6BOO.OO 4.19 42.$9 6178.15 6102.3~ 2572.18 1884.43 6900.00 1.29 42.89 6278.03 6202.23 2576,87 1887.87 END 3/100 DROP 6939.78 0.00 42.89 6337.80 62~2.00 2577.29 1888.27 KLTp D SHALE 7207,78 0-00 42.89 6485.80 6420.00 2fi77_29 1888.~7 KDP C 7[39.78 O.00 42.S9 6517.80 6442.00 2577.~9 1888 (Anadri[X (c)98 ~WEiO2P4 3.2b.5 3:14 PM P} I733.68 E 584709.73 5980127,69 LS 3.00 1743.97 E 584719.89 5980128.88 LS 3.00 1748.28 ~ $$472~.16 5980133.57 LS 3.00 1750.72 E 584726.56 5980236.22 43R 3.00 2753.92 H 584729.?2 5980139.~9 43R 3.00 1754.20 E 584730.00 5980140.00 43R 3.00 1754.20 E 584730.00 5980140.00 43R 0.00 176~.2D_.~ .... 584730.00 5960140.00 4~R_ .Q.0~ .... AKA-DPC F'EASIBIL. IZ¥ PLAN iNU-I V h_..M hUK EXECUTION Z ~D PROPOSED ~ELL PROFILE STATION IDENTIFICATION TARGET lfzJP A M I LUs;EACH MEASURED INCLN DIRECTION DEPTH D2~GLE AZIMUTH 7[B9.78 O,00 ~2.89 7430.78 0.00 42.89 7512~78 0.00 42.89 77~7.78 O.0O 42.8~ VERTICAL-DEPTHS SECTION TVD SUB-S~A DBPA/{T 6517.80 6~2.00 2577.29 66~3.80 6568.00 2577.29 ~B08.80 6733.00 2577.29 6890.80 6~15.00 257~.29 7125.80 7050.00 2577.29 06 Feb 1998 Page 3 == COORDINATES-FROM ALASKA Zome 4 WELL}{EAD X Y 15~8.17 N 175~.20 E 584730.00 5980140.00 18S~_I? N 1754.20 E 584730.~0 5980140.00 5888.L? N 1754.20 E ~84730.00 ~gE0]~0,00 1888.17 N 1754.20 E 584730.00 59SDl{O,00 1888,17 N 1754.20 E 584730.00 5980140.00 TOOL DL/ FACE .... =~== 43R 0.00 43R 0.o0 43R 0.00 43R O.O0 0.00 I ANADr~R[LL AKA-DPC i FEAS I S I t I TY p LA N NOT APPROVED FOR EXECUTION PLAN .... , :I:> Z ]> H Z (AJ/adril] (c)98 NWE302P4 3.2b.5 3:14 PM P] H131949 DATE lai797 PYMT INVOICE / CREDIT MEMO CK!2t797E COMMENTS: lng iNST- DESCRIPTION ompang peemit lication ~athg campoa ATrACHED CHECK IS IN PAYMENT FOR FTEMS DESCRIBED ABOVE. GROSS I00.00 to deill ,~oe, x5i2~ i2/i~/97I . ~ 00131949I V~NOO~ ~ ~ DISCOUNT NET 100.00 · WELL PERMIT CHECKLIST COMPANY ADMINISTRATION A..~ R D ,TE ENGINEERING APPR DA-J-E GEOLOGY WELL NAME/~--/ ,~//~.,2.~' /'- 4'5 ~ PROGRAM: exp~/dev [] redrll [] serv [] weltbore seg ' ann, disposal para req ', GEOL AREA ~:~'/~r'~'~ UNIT# ///_,~/'"..~,,.-,j ON/OFF SHORE ~ ,~ ~ 1 Permit fee attached .......... N 2. Lease number appropriate .................. N 3. Unique well name and number ............... N 4. Well located in a defined pool ................. N 5. Well located proper distance from drilling unit boundary. . . N 6. Well located proper distance from other wells ......... N 7. Sufficient acreage available in drilling unit. . . N 8. If deviated, is wellbore plat included N 9. Operator only affected party ...... N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order ....... N 12 Permit can be issued without administrative approval ..... N 13. Can permit be approved before 15-day wait ........... N 14. Conductor string provided ................ (~ NN 15. Surface casing protects all known USDWs ........... · 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casincl designs adequate for C, T, B & permafrost ..... 20. AdeqL~ate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations ......... 24 Drilling fluid program schematic & equip list adequale .... 25. BOPEs do they meet regulation ...... ~_.~.;,.~ ..... ~ N 26. BOPE press rating appropriate; test to ~~ psig. (xt'~. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~,~ N 28. Work will occur without operation shutdown ....... ~~ 29. Is presence of H:,S gas probable .............. ~~ 30. Permit can be issued w/o hydrogen sulfide measures 31~ Data presented on potential ov~rpressure zones .... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) .... /,/(.,',.,~ ..... 34. Contact name/phone for we,ekly,progress ret)o, ds ....... {exploratory only] GEOLOGY: ENGINEERING: COMMISSION: CO REMARKS N N Y N Comments/Instructions: 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. Date * ALASKA COMPUTING CENTER * * . * ............................ . * ....... SCHLUMBERGER ....... * * ............................. . COMPANY NAME : BP EXPLORATION WELL NAME : NWE 1-02 FIELD NAME : NWEILEEN BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292286500 REFERENCE NO : 98215 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/05/ 8 ORIGIN : FLIC REEL NAME : 98215 CONTINUATION # : PREVIOUS REEL COYJqENT : B.P. EXPLORATION, NWE 1-02, NW EILEEN, API #50-029-22865-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/05/ 8 ORIGIN · FLIC TAPE NAME : 98215 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : B.P. EXPLORATION, NWE 1-02, NWEILEEN, API #50-029-22865-00 TAPE HEADER NWEILEEN OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RUN 1 98215 V. LOMAX JAMES RAY WELL CASING RECORD 1ST STRING 2ND STRING NWE 1-02 500292286500 BP EXPLORATION SCHLUMBERGER WELL SERVICES 7-MAY-98 RUN 2 RUN 3 34 12N liE 2513 3918 77.20 75.70 46.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 2827.0 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 3RD STRING PRODUCTION STRING REPLARKS : CONTAINED HEREIN IS THE DATA ACQUIRED ON BP EXPLORATION WELL NWE 1-02 ON MARCH 21, 1998. TOOLS RUN: PEX/AIT, DSI, FMI, AND CMR. THE DSI, FMI, AND CMR DATA WAS DEPTH SHIFTED TO THE AIT GA~9~A RAY. THIS DATA IS PRESENTED IN A MODIFIED LDWG FORMAT AS PER DAVE DOUGLAS. THE FORMAT IS: FILE 1: FILE 2: FILE 3: FILE 4: FILE 5: FILE 6: FILE 7: FILE 8: FILE 9: $ $ CLIPPED & DEPTH CORRECTED DATA FROM ALL TOOLS ~ . 5 ' SAMPLE RATE. RAW PEX/AIT DATA, ALL CURVES @ .1667' RATE. RAW DSI DATA; ALL CURVES @ . 1667'RATE. RAW FMI DATA; ALL CURVES @ .1667' RATE. RAW CMR DATA; ALL CURVES @ .1667' RATE. RAW (REPEAT) PEX/AIT DATA; ALL CURVES @ .1667' SAMPLE RATE. RAW (REPEAT) DSI DATA; ALL CURVES ® .1667'. RAW (REPEAT) FMI DATA; ALL CURVES @ . 1667' . RAW (REPEAT) CMR DATA; ALL CURVES @ .1667'. PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 M~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUM2~ARY LDWG TOOL CODE PEX/AIT DSI FMI CMR $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 7598.0 2707.5 7595.5 2788.5 7597.5 6764.5 7589.0 6892.0 BASELINE DEPTH 88888.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... DSI FMI CMR 88888.5 88888.0 88887.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 7553.0 7529.0 7514.0 7508.5 7495.5 7495 0 7491 0 7488 5 7488 0 7474 5 7464 0 7384 0 7361.0 7359.5 7348.5 7308.5 7248.5 7248.0 7237.0 7207.5 7191.5 7190.5 7140 5 7140 0 7139 5 7122 0 7116 0 7113 5 7109 5 7103.5 7085.5 7085.0 7069.0 7066.5 7026.5 7015.5 7014 5 6990 0 6988 5 6953 5 6952 0 6949 0 6903 0 6890.5 6889.0 6873.0 6872.0 6865.5 6864.0 6836.0 6833.5 6818.0 6816.5 6798.0 6797.0 7514.5 7509.5 7495.0 7488.5 7361.0 7308.0 7248.0 7191.0 7139.5 7113.0 7084.5 7026.0 7015.0 6989.0 6952.5 6948.5 6889.5 6872.0 6864.5 6832.5 6817.0 6797.0 7495.0 7464.0 7348.5 7248.0 7236.5 7208.0 7190.5 7139.5 7103.5 7085.0 7067.0 7015.0 6989.0 6953.0 6903.5 6889.5 6872.0 6864.5 683 6.0 6816.5 6797.0 7552.5 7529.0 7509.0 7495.0 7491.0 7488.5 7474.5 7384.0 7359.5 7139.5 7122.0 7116.5 7109.5 7069.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 6781.5 6781.0 6773.5 6773.0 6762.0 6740.0 6727.0 6711.5 6697.0 6637.0 6624.0 6598.5 6596.0 6518.0 6496.5 6493 0 6440 0 6412 5 6395 0 6384 5 63 73 5 6353.5 6313.0 6291.0 6281.5 6267.0 62 63.5 6237.5 6226.5 6203.5 6193.0 6188.0 6179.5 6176.5 6164. 0 6121.5 6114.5 6088.0 6018.0 6002.5 5985.5 5979.0 5927.5 5908.0 5873.0 5836.5 5783.5 5748.5 5686.0 5668.5 5646.0 5638.0 5395.5 53 73.0 5345.5 6780.5 6772.5 6761.0 6739.0 6725.5 6710.5 6695.5 6636.0 6622.5 6597.5 6594.5 6516.5 6495.5 6491 0 6438 5 6411 0 6393 5 6383 0 6372 0 6352 0 6311 0 6289 5 6279.5 62 65.5 62 62.0 6236.5 6225.0 6202.0 6191.0 6286.0 61 77.5 61 74.5 6162.5 6120.0 6112.5 6086.5 6016.0 6001.5 5983.5 5977.5 5926.0 5906.5 5871.0 5834.5 5782.0 5746.5 5684.5 5667.0 5644.5 5636.5 5394.0 5371.5 5344.0 6781.0 6772.5 ', 8-MAY-!998 12:28 PAGE: 5 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 5333.5 5286.0 5266.0 5254.5 5198.5 5149.0 5098.0 5092.0 5033.0 5013.5 4951,0 4922.5 4893.0 4861.5 4847.5 4843 0 4809 5 4753 5 4737 0 4649 5 4628 0 4612.5 4541.0 4536.0 4525.0 4509.5 4480.0 4463.5 4431.5 4410.0 4384 5 4358 0 4332 0 4323 5 4305 0 4291 5 4256.0 4238.0 4227.5 4221.5 4196.5 42 71.5 4163.0 4143.0 4130.5 4127.5 4115.0 4091.5 4068.5 4050.0 4031.5 4006.0 3994.0 3974.0 3964.5 5331.5 5284.0 5263.0 5252 5 5197 0 5247 0 5097 0 5090 0 5031 0 5011 5 4949.5 4922.0 4891.5 4859.5 4845.0 4842.0 48O8.0 4752.5 4735.5 4648.0 4627.0 4611.0 4540.0 4535.0 4524.5 4508.5 4479.0 4462.5 4430.5 4408.5 4383.0 4356.5 4331.0 4322 0 4304 0 4289 5 4255 0 4237 0 4226 0 4220.5 4194.5 4170.0 4162.0 4141.5 4129.0 4126.5 4113.5 4090.5 4068.5 4048.5 4030.0 4004.5 3993.0 3973.0 3963.0 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 8-MAY-1998 12:28 PAGE: 3940.5 3939.5 3927.0 3926.0 3917.5 3916.5 3905.0 3904.0 3872.0 3870.5 3844.5 3843.0 3770.0 3768.5 3730.5 3729.0 3699.0 3697.5 3683.5 3682.0 3654 . 0 3652.5 3630.5 3629.0 3595.0 3593.5 3521.0 3519.5 3489.5 3488.0 3476.0 3474.5 3449.0 3447.5 3431.5 3430.0 3406.0 3404.5 3314.0 3312.5 3296.5 3295.5 3234.5 3233.0 3209.0 3207.5 3173.5 3172.0 3121.0 3119.5 3104.5 3103.5 3090.0 3088.5 3073.0 3071.5 3051.0 3050.0 3003.0 3002.0 2981.5 2980.0 2923.5 2922.0 2898.5 2897.0 2871.5 2870.0 2827.5 2826.0 2822.5 2821 . 0 2803.5 2802.5 2797.5 2796.5 100.0 99.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 99.5 100.0 RUN NO. PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE CLIPPED AND EDITED MAIN PASS PEX/AIT, DSI, FMI, AND CMR DATA PRESENTED AT .5' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: ** DATA FORIViaT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 3 73 188 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 5 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEMCODE (HEX) DEPT ............................ FT 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 SP AIT MV 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 GR AIT GAPI 1197037 O0 000 O0 0 1 I 1 4 68 0000000000 TENS AIT LB 119'7037 O0 000 O0 0 1 1 1 4 68 0000000000 TEND AIT LB 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 MRES AIT OHMM 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 MTEM AIT DEGF 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 DEV AIT DEG 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN OH~IMl197037 O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN OHlV~Il197037 O0 000 O0 0 1 1 1 4 68 0000000000 NINOR SDN OHI~dl197037 O0 000 O0 0 1 1 1 4 68 0000000000 AFiO AIT OHNIMl197037 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE~ NAME SERV UNIT SERVICE API API APi API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) AF20 AIT OHNk4 1197037 O0 000 O0 0 1 1 i 4 68 0000000000 AF30 AIT OH~4Iffl197037 O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT OHMM 1197037 O0 000 O0 0 I 1 1 4 68 0000000000 AF90 AIT OHMM 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 DTCO DAS US/F 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 DTSM DAS US/F 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 RSHC DAS 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 PR DAS 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 C24 FMS IN 1197037 O0 000 O0 0 1 I 1 4 68 0000000000 C13 FMS IN 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 RB1 FMS DEG 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 AZ FMS DEG 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 TCMR CMR PU-S 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CMFF CMR 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 CMRP CMR PU-S 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CFF3 CMR 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CFF4 CMR 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CFF5 CMR 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 CFF6 CMR 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 BFV CMR 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 KSDR CMR MD 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 KTIM CMR MD 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 T2LM CMR 1197037 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7582.000 SP.AIT -51.250 GR.AIT -999.250 TENS.AIT TEND.AIT 1082.232 MRES.AIT -999.2~0 M~!EM.AIT -999.250 DEV. AIT CNTC. CNT -999.250 CFTC. CNT ~99.9.2~0 FCNT. CNT -999.250 NCNT. CNT CRAT. CNT -999.250 NRAT. CNT -999.250 N~I.CNT -999.250 CPHI.CNT CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN MSFL.SDN -999.250 MINV. SDN -999.250 MNOR.SDN -999.250 AFIO.AIT AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT -999.250 AFgO.AIT DTCO.DAS -999.250 DTSM. DAS -999.250 RSHC.DAS -999.250 PR.DAS C24.FMS -999.250 Cl3.FMS -999.250 RB1.FMS -999.250 AZ.FMS TCMR.CMR -999.250 CMFF. CMR -999.250 CMRP. CMR -999.250 CFF3.CMR CFF4.CMR -999.250 CFF5.CMR -999.250 CFF6.CMR -999.250 BFV. CMR KSDR.CMR -999.250 KTIM. CMR -999.250 T2LM. CMR -999.250 DEPT. 2824.000 SP.AIT -20.938 GR.AIT 71.419 TENS.AIT TEND.AIT 930.306 MRES.AIT 0.164 MTEM. AIT 82.234 DEV. AIT CNTC. CNT 1610.568 CFTC. CNT 491.705 FCNT. CNT 453.541 NCNT. CNT CRAT. CNT 3.478 NRAT. CNT 3.668 NPHI.CNT 39.202 CPHI.CNT CAL1.SDN 11.339 DRHO.SDN -0.040 PEF. SDN 2.771 RHOB.SDN MSFL.SDN 1.782 MINV. SDN 1.397 RiNOR.SDN 1.287 AFiO.AIT AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT -999.250 AF90.AIT DTCO.DAS 136.883 DTSM. DAS 363.619 RSHC. DAS 2.656 PR.DAS C24.FMS -999.250 Cl3.FMS -999.250 RB1.FMS -999.250 AZ.FMS TCMR.CMR -999.250 CMFF. CMR -999.250 CMRP. CMR -999.250 CFF3.CMR 3647.000 -9.99.250 -999.250 -999.250 -9.99.250 -999.250 -999.250 -999.250 --999.250 -999.250 -999.250 2049.000 26.220 1556.757 36.866 2.158 -999.250 -999.250 0.417 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska CompuTing Center 8-MAY-1998 12:28 PAGE: CFF4.CMR -999.250 CFF5.CMR KSDR.CMR -999.250 KTIM. CMR -999.250 CFF6.CMR -999.250 T2LM. CM~ -999.250 -999.250 -999.250 * * END OF DA TA * * **** FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW OPEN HOLE MAIN PASS Curves and log header data fou each ru.n and too~ st~ing in s~arate files; Tool String #1 .fo Sadlerochit run presented first: (primary depth control string used to depth shift the Sadler interval) followed by files foz' or, her main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEX 7598.0 2707.5 AIT 7598.0 2707.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : 21-MAR-98 8Cl-205 1200 21-MAR-98 0015 22-MAR-98 7583.0 7582.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 10 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED {FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (?T) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 2824.0 7574.0 1800.0 TOOL NUMBER AIT-H HILTB -DTB 8.500 2827.0 2824.0 LSND 11.40 81.0 8.9 180.0 O. 185 7O. 0 O. 131 62.0 O. 207 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR TI¢ERMAL) : MA TR.'fiX: MATRIX DENSITY: IIOLE CORRECTION (IN): THERMAL SANDS TONI,; .9.. 6'5 TOOL STANDOFF (IN): REMARKS: RIG: NABORS 18-E. RAN STANDOFFS ON THE AIT AND BOWSPRING .ECCENTRALIZER ON THE HGNS. PULLED TIGHT AT 6770'. THIS FILE CONTAINS THE RAW PEX/AIT MAIN PASS DATA WITH ALL CURVES AT .1667 SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 192 4 66 1 5 66 6 73 7 65 8 68 O. 166 9 65 FT 11 66 5 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1197037 O0 000 O0 0 2 i 1 4 68 0000000000 SP AIT MV 1197037 O0 000 O0 0 2 1 i 4 68 0000000000 GR AIT GAPI 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 T~g AIT LB 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 ~'I"ENAI'T LB 1197037 O0 000 O0 0 2 ~ 1 4 68 0000000000 MRES AIT OHMM 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 MT~;~ AIT D.EGF 1197037 O0 000 O0 0 2 i 1 4 68 0000000000 GDEV AIT DEG 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC PEX CPS 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC PEX CPS 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT PEX CPS 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 RCNT PEX CPS 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 TNRA PEX 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 RTNR PEX 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH PEX PU 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI PEX PU 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 NPOR PEX PU 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 HCAL PEX IN 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 RHOZ PEX G/C3 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 HDRA PEX G/C3 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 PEFZ PEX 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 DPHZ PEX PU 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 H~IN PEX 0HF~41197037 O0 000 O0 0 2 1 1 4 68 0000000000 H~NO PEX OHIO4 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 RXOZ PEX 0H~1~1197037 O0 000 O0 0 2 1 1 4 68 0000000000 RX08 PEX 0H~II197037 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 12 NAME SERVUNIT SERVICE API API API API FILE NUMB NO?4B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO~B SAMP ELEM CODE (HEX) HCNT PEX CPS 1197037 O0 000 O0 0 2 1 i 4 68 0000000000 HCFT PEX CPS 1197037 O0 000 O0 0 2 1 i 4 68 0000000000 HGR PEX GAPI 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 RHFT PEX CPS 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 RHNT PEX CPS 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 HTNP PEX PU 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 HNPO PEX PU 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 AOiO AIT OHT~Ml197037 O0 000 O0 0 2 1 1 4 68 0000000000 A020 AIT 0H~4~1197037 O0 000 O0 0 2 1 1 4 68 0000000000 A030 AIT OPiNI~l197037 O0 000 O0 0 2 1 1 4 68 0000000000 A060 AIT 0Hi~1197037 O0 000 O0 0 2 1 1 4 68 0000000000 A090 AIT OHIVi~l197037 O0 000 O0 0 2 1 1 4 68 0000000000 ATiO AIT OHIV~l197037 O0 000 O0 0 2 1 1 4 68 0000000000 AT20 AIT OHI~ 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 AT30 AIT OHm 1197037 O0 000 O0 0 2 1 2 4 68 0000000000 AT60 AIT 0HN~11197037 O0 000 O0 0 2 1 1 4 68 0000000000 AT90 AIT OHI~M1197037 O0 000 O0 0 2 1 1 4 68 0000000000 AFiO AIT OHP~ff 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 AF20 AIT OHIO41197037 O0 000 O0 0 2 1 1 4 68 0000000000 AF30 AIT OHIvlM 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 AF60 AIT OHNiM1197037 O0 000 O0 0 2 1 1 4 68 0000000000 AF90 AIT OHMM 1197037 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. HTEN. AIT CNTC. PEX '.I'NRA PEX NPOR PEX .PEFE PEX RXOZ PEX HGR PEX HNPO PEX AO60.AIT AT30. AIT AF20. AI T DEPT. HTEN. AIT CNTC. PEX TNRA.PEX NPOR.PEX PEFZ.PEX RXOZ.PEX HGR.PEX HNPO. PEX AO60.AIT AT30.AIT 7598.000 172.079 1860.385 3 428 39 730 -999 250 0 532 166 654 39 730 2 147 2 024 1 941 2702.500 1317.195 1157.053 4.001 45.283 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SP.AIT MRES.AIT CFTC.PEX R ~WR. PEX HCAL. PEX DPHZ. PEX RXO8.PEX RHFT. PEX AOiO.AIT AO90.AIT AT60.AIT AF30.AIT SP.AIT MRES.AIT CFTC. PEX RTNR.PEX HCAL.PEX DPHZ.PEX RXO8.PEX RHFT. PEX AOiO.AIT AO90.AIT AT60.AIT -50.000 0.107 553.449 3.685 8.053 60721 211 0 532 503 221 1 373 2 151 2 138 2 091 12.625 0.168 309.507 4.616 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 GR.AIT .7. 66. 654TENS.AIT 2328. 000 MTEM. AIT 7.37. .~0~ GDEV.AIT -999.250 RCFT. PEX 503. 221 RCNT. PEX 1 786. 899 TNPtt. PEX 40.4 82 NPHI. PEX 42.5 72 RHOZ.PEX - 999.250 HDRA.PEX --999.250 HMIN. PEX 0.,!t88 HMNO.PEX O. 470 HCNT. PEX .'I 860. 385 HCFT. PEX 553 . 449 RHNT. PEX 1786.899 HTNP.PEX 40.482 AO20.AIT 1 . 942 AO30.AIT 1 . 999 ATIO.AIT 1 . 373 AT20.AIT 1 . 939 AT90.AIT 2. 161 AFIO.AIT 1 . 373 AF60.AIT 2. 154 AFgO.AIT 2. 148 GR.AIT 34.242 TENS.AIT MTEM. AIT 82.234 GDEV. AIT RCFT. PEX 303.573 RCNT. PEX TNPH. PEX 46.560 NPHI.PEX RHOZ.PEX -999.250 HDRA.PEX HMIN. PEX -999.250 HIVlNO. PEX HCNT. PEX -999.250 HCFT. PEX RHNT. PEX -999.250 HTNP. PEX AO20.AIT -999.250 AO30.AIT ATiO.AIT -999.250 AT20.AIT AT90.AIT -999.250 AFiO.AIT 1946.000 26.496 1171.931 52.248 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing CenTer 8-MAY-1998 12:28 PAGE: 13 AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT -999.250 AFgO.AIT -999.250 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS C'~.~'~ve~,,~ a~'~d ~og header data .for each .uu~ and ~oo? ,~'tm.'ing it~ separate .files; Tool Stz~ing ~1 fo ,gar~'ocl'L~t' rt~ presented first (primary depth ~':'o~'o~ ,st~.'.img used Uo depth shif~ the Sad]e~ i.n~:~:u"va_~.) f'ollowed by files .for other main RUN NUMBER: .l TOOL STRI'NG NUMBER: 2 PASS NUMBER: 1 DEPTH INCREMENT: O. 1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH .DSI 7595.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) '. TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : STOP DEPTH 2788.5 21-MAR-98 8Cl-205 1200 21-MAR-98 0015 22-MAR-98 7583.0 7582.0 2824.0 7574.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 14 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DSI DIPOLE SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OH~ff) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL O.R THERMAL): MATRIX: MATRIX DENSITY: IIOI,E CORRF, CTION (IN): 7'OOb STANi)OFF (.TN): 1800.0 TOOL NUMBER ........... DSST-B 8.500 2827.0 2824. 0 LSND 11.40 81.0 8.9 180.0 0.185 70.0 O. 131 62.0 0.207 62.0 THERMAL SANDS TONE 2.65 REMARKS: RIG: NABORS 18.-E. DIPOLE SONIC RAN WITH 1.5 INCH STANDOFFS. GPIT RAN FOR ORIENTATION FOR BCR-CROSSDIPOLE DATA MODES RAN UPPER AND LOWER DIPOLE, P+S, BCR CROSS-.. DIPOLE. THIS FILE CONTAINS THE RAW DSI MAIN PASS DATA WITH ALL CURVES AT . 1667 SAMPLE RATE. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER #LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1197037 O0 000 O0 0 3 1 1 4 68 0000000000 GR DSI GAPI 1197037 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DSI LB 1197037 O0 000 O0 0 3 1 1 4 68 0000000000 DTCO DS~ US/F .?..797037O0 000 O0 0 3 i ~ 4 68 0000000000 DTSM DS'I US/F .1 l !)7037 O0 000 O0 0 3 1 1 4 68 0000000000 RSI.tC D,g~' 1.197037 O0 000 O0 0 3 1 I 4 6'8 0000000000 PR I)SI' 12.9703'7 O0 000 O0 0 3 I 1 4 68 0000000000 ** DATA ** DEPT. 7603.500 GR.DSI -999.250 TENS.DSI -999.250 DTCO.DSI -999.250 DTSM.DSI --99.9.250 RSHC.DSI -999.250 PR.DSI -999.250 DEPT. 2777.500 GR.DSI -999.250 TENS.DSI -999.250 DTCO.DSI -999.250 DTSM. DSI -999.250 RSHC.DSI -999.250 PR.DSI -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT . 003 SERVICE : FLIC VERSION : 001 CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAi4 REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and .log header data for each run and tool string in separate files,. Tool String #1 fo Sadlerochit .run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 3 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 F"I [,E SUMMA R Y VENDOR TOOL (7(2D1~ S'.FAi?T I)EPTII FMI 7597.5 $ LOG HEADER DATA DA~E LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): S TOP D.EP Tt.I 67~4.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE FMI FORMATION MIC. IMAG. $ 21-MAR-98 8Cl-205 1200 21--MAR-98 0015 22-MAR-98 7583.0 7582.0 2824.0 7574.0 1800.0 TOOL NUMBER DSST-B LIS Tape Verification Listing Schlumberger Alaska Compu ting Cent er 8-MAY-1998 12:28 PAGE: 17 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 2827.0 2824.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 11.40 MUD VISCOSITY (S) : 81.0 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 180.0 RESISTIVITY (OH~ff) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.185 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 131 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 207 MUD CAKE AT (BHT) : 70.0 62.0 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: RIG: NABORS 18-E. RAN STANDOFFS ON THE FMI CARTRIDGE TO IMPROVE TOOL CENTRALIZATION. RAN 7%70 PASSES ON DIFFERENT FMI GAIN SETTINGS TO ENSUt.~E I-IIGttE,ET POSSIBLEDATA QUALITY. Tl.tl',g F?[iE CONTAINS TItE RAN FMI MAIN PA,ES DATA (GATN:~ AUTO HIGH) WITH ALL CURVES AT .1667 SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 8-MAY-1998 12:28 PAGE: 18 TYPE REPR CODE VALUE 7 65 8 68 0.166 9 65 FT 21 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1197037 O0 000 O0 0 4 1 1 4 68 0000000000 GR FMI GAPI 1197037 O0 000 O0 0 4 1 1 4 68 0000000000 TENS FMI LB 1197037 O0 000 O0 0 4 1 1 4 68 0000000000 GDEV FMI DEG 1197037 O0 000 O0 0 4 1 1 4 68 0000000000 C2 FMS IN 1197037 O0 000 O0 0 4 1 1 4 68 0000000000 C1 FMS IN 1197037 O0 000 O0 0 4 1 1 4 68 0000000000 RB1 FMS DEG 1197037 O0 000 O0 0 4 1 1 4 68 0000000000 HAZI FMS DEG 1197037 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEP'F. 7597. 000 GR. C.2. FM,g 7.229 C? . FMS DEPT. 6764.500 C2.~'~S -999.250 ?. 07. 584 'FENS. FMI' 2577. 000 GDEV. '7. 7'~,0 kB7.. FMS 8(i'. 69(~ HAZ.7-. FM,q GR.FMI 250.780 TENS.FMI 3.139,000 GDEV. FMI Cl.P~S --999.250 RB1.FMS 290.574 I~ZI.FMS ,'] 0. '? 09 14. 352 33. 863 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 19 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool s~rings per run. RUN NUMBER: TOOL STRING NUMBER: 4 PASS NUMBER: DEPTH INCREMENT: O. 1667 FILE SUNk~ARY VENDOR TOOL CODE START DEPTH CMR $ LOG HEADER DATA DATE LOGGED: 7589.0 SOFTWARE VERSION: TIME CIR C[2LA TION .ENDI!?!') : TTMh? I,C;GGER ON ~VYI'TOIV[: TI) I)£~F. LI,ER (FT') : ~D I.,OGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEh~D (FPHR) : STOP DEPTH 6892.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CMR COMB. MAG. RES. IMAG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 21 .-MAR-98 8C1-2O5 1200 21--MAR--98 0015 22.MAR-.98 7583. 0 7582. 0 2824. 0 7574. 0 1800. 0 TOO.r, NUMBER CMR T 8.500 2827.0 2824.0 LSND 11.40 81.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8~MAY-1998 12:28 PAGE: 20 ~FUD PH : 8.9 FLUID LOSS (C3): MA~YIICO~! RECORDED TEMPERATURE (DEGF) : 180.0 RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 185 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 131 MUD FILTRATE AT (BHT): MUD CAKE AT (MT): O. 207 MUD CAKE AT (BHT): 70.0 62. 0 62. 0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERiViAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN) : REMARKS: RIG: NABORS 18-E. RAN MULTIPLE PASSES OVER THE PRIMARY ZONE OF INTEREST WITH DIFFERENT PARAMETERS AS LABELED. THIS FILE CONTAINS THE RAW CMR MAIN PASS DATA (WAIT TIME = 4S) WITH ALL CURVES AT .1667 SAMPLE RATE. NOTE: CMFF, BFV, & KTIM ARE FROM THE TAPER CUTOFF PROCESSING. ALSO, CMRP IS ACTUALLY CMRP 3ms. LIS FORMAT DATA ** DAT'A I,'OI~MA'I' ,?Pti,'Cl'I:"[ CAT] ON REC.'ORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 21 ** SET TYPE - CH_AN ** NAME SERV UNIT SERVICE API API APIAPI FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 GR CMR GAPI 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CMR LB 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 TCMR CMR PU 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 CMFF CMR 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 CMRP CMR PU 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 CFF3 CMR 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 CFF4 CMR 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 CFF5 CMR 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 CFF6 CMR 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 BFV CMR 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 KSDR CMR MD 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 KTIM CMR MD 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 T2LM CMR 1197037 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 7589.000 GR.CMR 84.706 TENS. CMR 1464.000 TCMR.CMR CMFF. CMR 0.014 CMRP. CMR 0.092 CFF3.CMR 0.033 CFF4.CMR CFFS.CMR 0.012 CFF6.CMR 0.012 BFV. CMR 0.151 KSDR.CMR KTIM. CMR 0.064 T2LM. CMR 11.424 DEPT. 6892. 000 GR. CMR 140. 748 TENS. CI~R 3046. 000 TC~R. CMR CMFF. CMR 0. 025 CN~RP. d~MR O. .7 6'4 CFF3 . CMR 0. 066 C?'F,']. CMR CFF5. CMR 0. 012 Cf;'F6. ('Mk O. 000 BFV. CMR 0.278 A',q]~[~. CMI~ I<TIM. CMR 0.463 'l'2.l_,M. CMf< 9. 46'7 0.165 0.012 0.049 0.243 0.0~9 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 22 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUNk~ARY FILE HEADER FILE NUMBER 6 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings .per run. 1 1 2 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH PEX 7422.0 6894.5 AIT 7422.0 6894.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI'ME C.TleCUI,A 7'I.'C)N I",NI)t?I?: TIME LOGGER ON I_~O'!'[I'OM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INT.ERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX PLATFORM EXPRESS $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: 2_7. -,NAR .- 98 8C.ZZ -205 00'15 22 -MAR .. 98 7583. 0 7582. 0 2824. 0 7574. 0 1800. 0 TOOL NUMBER AIT-H HILTB -DTB 8.500 2827.0 2824.0 LSND LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 23 ~fUD DENSITY (LB/G): 11.40 MUD VISCOSITY (S) : 81.0 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 180.0 RESISTIVITY (0~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 185 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. I31 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 207 MUD CAKE AT (BHT) : 70.0 62.0 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: RIG: NABORS 18-E. RAN STANDOFFS ON THE AIT AND BOWSPRING ECCENTRALIZER ON THE HGNS. PULLED TIGHT AT 6770'. THIS FILE CONTAINS THE RAW PEX/AIT REPEAT PASS DATA WITH ALL CURVES AT .1667 ,_q. AMP~.,E RATE. $ LIS FORMAT DATA ** DATA I""OI?MAT SPECIi;'ICATION RE(Z'OI~I.~ ** ** SET TYPE - 64EB ** TYPE .REPR CODE VA ~,UE 1 66 0 2 66 0 3 73 192 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 5 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger A1 aska Compu ting Cen ~ er 8-MAY-1998 12:28 PAGE: 24 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** N~ME SERV UNIT SERVICE API API API AP2 FILE NUIVIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 SP AIT MV 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 GR AIT GAPI 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 TENS AIT LB 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 HTEN AIT LB 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 MRES AIT OHMM 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 MTEM AIT DEGF 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 GDEV AIT DEG 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PEX CPS 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PEX CPS 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PEX CPS 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PEX CPS 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PEX 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PEX 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PEX PU 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PEX PU 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PEX PU 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 HCAL PEX IN 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 RHOZ PEX G/C3 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 HDRA PEX G/C3 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 PEFZ PEX 1297037 O0 000 O0 0 6 1 1 4 68 0000000000 DPHZ PEX PU 1297037 O0 000 O0 0 6 1 2 4 68 0000000000 t.tMIN PEX O~IMM 2~9703'? O0 (100 O0 0 ~ 1 .7 ~1 68 0000000000 HMNO PEX OI.~MNI 119'/037 O0 000 O0 0 il 2 1 4 68 0000000000 RXOE PEX OHMM 1197037 O0 000 O0 0 6 1 2 4 68 0000000000 RX08 PEX OHMM 1197037 O0 000 O0 0 6 I 1 4 68 0000000000 HCNTPEX CPS 1197037 O0 000 O0 0 6 I I 4 68 0000000000 HCFT PEX CPS 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 HGR PEX GAPI 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 RHFT PEX CPS 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 RHNT PEX CPS 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 HTNP PEX PU 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 HNPO PEX PU 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 AOiO AIT OHMi~ 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 A020 AIT OH~ 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 A030 AIT OHMM 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 A060 AIT OHiV~ll197037 O0 000 O0 0 6 1 1 4 68 0000000000 A090 AIT OHIV~lI97037 O0 000 O0 0 6 1 1 4 68 0000000000 ATIO AIT OHIV~llI97037 O0 000 O0 0 6 1 1 4 68 0000000000 AT20 AIT 0HP~1197037 O0 000 O0 0 6 1 1 4 68 0000000000 AT30 AIT 0HI~Ii197037 O0 000 O0 0 6 1 1 4 68 0000000000 AT60 AIT 0It~1197037 O0 000 O0 0 6 1 1 4 68 0000000000 AT90 AIT 0H~1197037 O0 000 O0 0 6 1 1 4 68 0000000000 AFiO AIT 0HFi~1197037 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 25 NAME SERV UNIT SERVICE API API API API FILE NU~IB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB S,z2~P ELEM CODE (HEX) AF20 AIT 0H7~41197037 O0 000 O0 0 6 1 1 4 68 0000000000 AF30 AIT OH~R41197037 O0 000 O0 0 6 1 1 4 68 0000000000 AF60 AIT OHMM 1197037 O0 000 O0 0 6 1 1 4 68 0000000000 AF90 AIT OH3~ 1297037 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 7422.000 SP.AIT -30.000 GR.AIT 135.407 TENS.AIT HTEN. AIT 882,471 MRES.AIT 0.112 MTEM. AIT 136,505 GDEV. AIT CNTC. PEX 2349.760 CFTC. PEX 832.236 RCFT. PEX 742.280 RCNT. PEX TNRA.PEX 2.864 RTNR.PEX 3,078 TNPH.PEX 31.790 NPHI.PEX NPOR.PEX 31,285 HCAL.PEX 8.333 RHOZ.PEX -999,250 HDRA.PEX PEFZ.PEX -999,250 DPHZ.PEX 60721.211 HMIN. PEX 0.172 HMNO.PEX RXOZ.PEX 0.030 RXO8.PEX 0,030 HCNT. PEX 2349.760 HCFT. PEX HGR.PEX 135.407 RHFT. PEX 742,280 RHNT. PEX 2249.335 HTNP.PEX HNPO. PEX 31.285 AOiO.AIT 2.273 AO20.AIT 2,993 AO30.AIT AO60.AIT 3. 023 AO90.AIT 2. 819 ATIO.AIT 2.277 AT20.AIT AT30.AIT 2. 981 AT60.AIT 3. 036 ATgO.AIT 2. 803 AFiO.AIT AF20.AIT 3. 001 AF30.AIT 3. 040 AF60.AIT 3. 017 AFgO.AIT DEPT. 6894.500 SP. HTEN. AIT 1073.863 MRES. CNTC. PEX 1484.422 CFTC, TNRA.PEX 3.451 RTNR NPOR.PEX 40.788 HCAL PEFZ.PEX 4.507 DPHZ RXOZ. PEX 0.108 RX08 tIGR. P~i~ 141 . 2 3 8 IfNPO. PL~Y 4 ~. 904 A O_l. 0 AO60.AIT .1.28.9 A090 AT30.AIT 2.195 AT60 AF20.AIT ~.232 AF30 AIT -33. 813 GR.AIT AIT 0. ,114 MTEM. AIT PEX 435.027 RCFT. P.EX PEX 3.7.10 TNPH, PEX PEX - 999. 250 RHOZ. PEX .PEX 2 6.005 I IMIN. PEX PRX 0. ~ 74 ItCN'F. PEX I:~I',',\' 4 ?, 7, 73 ?FWN'.I'. PI'L¥ Ai'T 0. ',~(_;'/ zi(l;,~ 0. A 1T AIT 1.234 A'I'IO.AIT AIT 1.250 AT90.A~T ATT I . 323 A P'(~O. ATT 135. 574 TENS.AIT 129. 410 GDEV.AIT 413. 400 RCNT. PEX 40. 749 NPHI. PEX 2.386 HDRA. PEX 0.170 HMNO. PEX 475, 94.9 HCF'.F. PRX 538. 477 .H'.I'NP. PI~X i. 49.:'? AO30.AZT O. 806 A'.F20.AIT 1. 195 AFiO.AIT 1.286 AFgO.AIT 2562.000 -999.250 2249.335 32.076 -999.250 0.052 832.235 31,790 2,949 2,998 2.276 2.804 3827.000 7.124 1530.077 42.29l 0.014 0.145 419.867 4 2. ~ 5 U ~ . ~ ~.t .~. 0.808 ?.2~9 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~ 8-MAY-1998 12:28 PAGE: 26 LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE · 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 2 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 7362.0 6997.5 DSI $ LOG HEADER DATA DATE LOGGED: 2 l -MAR- 98 SOFTWARE VERSION: SC1 .-205 TIME CIRCULATION ENDED: ?200 2?.-MAR-98 [FTME LOGGEt~ ON BOTTOM: Ool~ .?.;? .NIAR-!?8 il'Z) I]i~.iLLEI~ (l'".I") : '15~' ~. 0 TD LOGGER (FT) : '7~'82. 0 TOP LOG INTERVAL (FT) : 2824. 0 ~OTTOM LOG INTERVAL (FT) : 7~74. 0 LOGGING SPEED (EPHR) : 3.800. 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DSI DIPOLE SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : TOOL NUMBER DSST-B 8.500 2827.0 2824.0 LSND 11.40 81.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 27 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUN RECORDED TEMPERATURE {DEGF) : t 80.0 RESISTIVITY (OHNk4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.185 MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): O. MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 207 MUD CAKE AT (BHT) : 70.0 62.0 62.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: RIG: NABORS 18-E. DIPOLE SONIC RAN WITH 1.5 INCH STANDOFFS. GPIT RAN FOR ORIENTATION FOR BCR-CROSSDIPOLE DATA. MODES RAN UPPER AND LOWER DIPOLE, P+S, BCR CROSS.- DIPOLE. THIS FILE CONTAINS THE RAW .DSI REPEAT PASS DATA WITH ALL CURVES AT . 1 667 SAMPLE RATE. $ LIS FORMAT DATA DATA I,'ORMA'I' Si~E(']t;'I (_1'AT'ION I~ECOI~D ** ** SET TYPE - 64EB ** TYPE REPR CODE VA T_,UE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ~ 8-MAY-1998 12:28 PAGE: 28 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** SET TYPE - CHA~V ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX,! DEPT FT 1197037 O0 000 O0 0 7 i 1 4 68 0000000000 GR DSI GAPI 1197037 O0 000 O0 0 7 1 1 4 68 0000000000 TENS DSI LB 1197037 O0 000 O0 0 7 1 1 4 68 0000000000 DTCO DSI US/F 1197037 O0 000 O0 0 7 1 1 4 68 0000000000 DTSM DSI US/F 1197037 O0 000 O0 0 7 1 1 4 68 0000000000 RSHC DSI 1197037 O0 000 O0 0 7 1 1 4 68 0000000000 PR DSI 1197037 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 7362.000 GR.DSI DTSM.DSI 142.332 RSHC.DSI DEPT. 6997.500 GR.DSI DTSM.DSI 243.263 RSHC.DSI 72.000 TENS.DSI 4121.000 DTCO.DSI 1.447 PR.DSI 0.043 114.782 TENS.DSI 4235.000 DTCO.DSI 2.105 PR.DSI 0.354 98.348 115.554 ** END OF DAT~ ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC V h,'l?,~ ~ (IN : 0 0 .?. CO 'l J~.,'VI't'; : :)Q/Ox,/ ~:~ MAX REC SIZE : _l 024 LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW OPEN HOLE MAIN PASS LIS Tape Verification Listing Schluu~berger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 29 Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control s~ring used to depth shift ~he Sadler interval) followed by files for other main pass tool strings per run. RUN AFu?4BER: 1 TOOL STRING NTJ~IBER: 3 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SUMiVLARY VENDOR TOOL CODE START DEPTH FMI 7426.0 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH .......... 6974.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE FMI FORMATION MIC.IMAG. $ t~OREttOI.,E AND CASING DATA OPEN HOLE BIT SIZE (IN): ~')I~ I'I,~,~)?R,? CAS ~NG I')I.,~T~'F/1 (F'.I') : I~,OGGEI~S CASXNG DEP'I'i~ (FT) : ]30REHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHPk~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: 21-MAR-98 8Cl-205 1200 21.MAR-98 0015 22.-MAR-98 7583.0 7582.0 2824.0 7574.0 1800.0 TOOL NlrB.ER DSST-B 8.500 282 '/. 0 2 ~2 .I. 0 11.40 81.0 8.9 180.0 O. 185 70. 0 O. 131 62. 0 0.207 62.0 THERMAL SANDSTONE 2.65 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cen~er 8-MAY-1998 12:28 PAGE: 30 HOLE CORRECTION (IN): TOOL STANDOFF (IN): RF~IARKS: RIG: NABORS 18-E. RAN STANDOFFS ON THE FMI CARTRIDGE TO IMPROVE TOOL CENTRALIZATION. R_~N S~O PASSES ON DIFFERENT FMI GAIN SETTINGS TO ENSURE HIGHEST POSSIBLE DATA QUALITY. THIS FILE CONTAINS THE RAW FMI REPEAT PASS DATA WITH ALL CURVES AT .1667 SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.16'6 9 65 FT .7. 2 ~;' ~ .] 3 66' 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1197037 O0 000 O0 0 8 1 1 4 68 0000000000 GR FMI GAPI 1197037 O0 000 O0 0 8 1 1 4 68 0000000000 TENS FMI LB 1197037 O0 000 O0 0 8 1 1 4 68 0000000000 GDEVFMI DEG 1197037 O0 000 O0 0 8 1 1 4 68 0000000000 C2 FMS IN 1197037 O0 000 O0 0 8 1 1 4 68 0000000000 Cl ~-~IS IN 1197037 O0 000 O0 0 8 1 1 4 68 0000000000 RB1 FMS DEG 1197037 O0 000 O0 0 8 1 1 4 68 0000000000 HAZI FMS DEG 1197037 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 8-MAY-1998 12:28 PAGE: $1 ** DATA ** DEPT. 7426. 000 GR. FMI 1 O1 . 921 TENS. F~I 2521 . 000 GDEV. FMI C2. FMS 9. 325 C1. FMS 9.178 RB1. FMS 354.113 HAZI. FMS DEPT. 6974.500 GR.FMI 125.228 TENS.FMI 318~.000 GDEV. FMI C2.FMS -999.250 Cl.FMS -999.250 RB1.FMS 4.545 HAZI.FMS 9.300 40.960 10.392 41.825 * * END OF DATA * * * * * * FILE TRAILER * * * * FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ $ MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * FILE HEADER * * * * FILE .NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE : 102d FI I'H:?, TY'PF; : LO I,AHT' t,'1 1,I< : FILE HEADER FILE NUMBER 9 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool sSring in separate f~'.~es; Tool String #~ fo Sadlerochit run presented .first (primary depth control string used to dept:h shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 4 PASS NUMBER: 2 DEPTH INCREMENT: O. 1667 FILE SU~f4ARY VENDOR TOOL CODE START DEPTH CMR 7110.0 $ STOP DEPTH .......... 6890.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 32 LOG H~DER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) I~OGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CMR COMB.MAG.RES.IMAG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PI-I : FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BttT) MUD t?TI',TRATE AT (MT): IVlUD I,'Ii,'IT<A'FI,; AT' (BUT) : MIII~ (.'ANI,; A'I' (NI(I? : Miff) CAKE AT (Bt:fT) : NEUTRON T()OL TOOL TYPE (EPITHERMAL OR THERMAL): MA TR I'X: 21-MAR-98 8C1-205 1200 21-FL~R-98 0025 22-MAR-98 7583.0 7582.0 2824.0 7574.0 1800.O TOOL NUMBER CMRT 8. 500 2827.0 2824.0 LSND 11.40 81.0 8.9 180.0 0.185 '70.0 O. 137 (42. {,.?. 0 MA ~'!R IX DENSITY: IIOF,E CORRECTION (IN): THERMAL SAND S TONE 2. (45 TOOL STANDOFF (IN): REMARKS: RIG: NABORS 18 -E. ~ MULTIPLE PASSES OVER THE PRIMARY ZONE OF INTEREST WITH DIFFERENT PARAMETERS AS LABELED. THIS FILE CONTAINS THE RAW CMR REPEAT PASS DATA (WAIT TIME = 4s) WITH ALL CURVES AT .1667 SAMPLE RATE. NOTE: CMFF, BFV, & KTIM ARE FROM THE TAPER CUTOFF PROCESSING. ALSO, CMRP IS ACTUALLY CMRP 3ms. _ $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-MAY-1998 12:28 PAGE: 33 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERV UNIT SF:RVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (tIEX) DEPT FT 1197037 O0 000 O0 0 9 2 1 4 ~;$ 0000000000 GI~ CMR GAPT 7 ? 970.27 O0 000 O0 0 .9 'I'('NIt< ('.'MA~ ~',~1 'l 19'/0.~7 O0 C.~klt~t.~ CMRPU ~ ~ 97037 O0 000 O0 C'I,"F3 CMI~ Z197037 O0 000 O0 0 9 2 i 4 68 0000000000 CFF4 CMR 2297037 O0 000 O0 0 9 I 1 4 68 0000000000 CFF5 CMR 1197037 O0 000 O0 0 9 2 1 4 68 0000000000 CFF6 CMR 1197037 O0 000 O0 0 9 1 2 4 68 0000000000 BFV CMR 1197037 O0 000 O0 0 9 1 1 4 68 0000000000 KSDR CMR MD 2197037 O0 000 O0 0 9 ~ 2 4 68 0000000000 KTIM CMR MD 1197037 O0 000 O0 0 9 1 1 4 68 0000000000 T2LM CMR 1197037 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 7110.000 GR.CMR 63.529 TCMR.CMR 0.134 CMFF. CMR CMRP. CMR 0.115 CFF3.CMR 0.070 CFF4.CMR 0.015 CFF5.CMR CFF6.CMR 0.003 BFV. CMR 0.108 KSDR.CMR 0.137 KTIM. CMR T2LM. CMR 10.254 O. 026 O. 005 O. 187 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 8-MAY-1998 12:28 PAGE: 34 DEPT. 6890.500 GR.CMR C~4~P. CMR 0.146 CFF3.CMR CFF6.CMR 0.004 BFV. CMR T2LM. CMR 5.442 163.000 TCMR.CMR 0.061 CFF4.C~IR 0.195 KSDR.CMR 0.216 O. 013 0.258 CMFF. CMR CFFS. CMR KTIM. CMR 0.022 0.007 0.255 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 8 MAX REC SIZE' : ~024 FILE TYPE :.bO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT .DATE : 98/05/ 8 ORIGIN : FLIC TAPE NAME : 98215 CONTINUATION # : .l PREVIO[~ TAPE : COMMENT : B.P. E'XPLORATION, NWE 1-02, NN EILEEN, API #50-029-.228~5~00 SERVICE NAMI;t 1~.,~ 'l REtZ£, NAME CONT.I.'NUATI ON # PREVIOUS REEL COMMENT FI, II' B.P. EXPLORATION, NWE 1-02, NW EILEEN, API #50-029-22865-00
