Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
193-059
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P1-21 PRUDHOE BAY UN PTM P1-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 P1-21 50-029-22363-00-00 193-059-0 G SPT 8676 1930590 3000 2436 2440 2443 2444 290 385 386 381 REQVAR P Brian Bixby 4/10/2025 MITIA as per AIO 4G.005 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P1-21 Inspection Date: Tubing OA Packer Depth 690 3275 3101 3063IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250411043459 BBL Pumped:1.7 BBL Returned:1.6 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 11:15:17 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P1-21 PRUDHOE BAY UN PTM P1-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/22/2025 P1-21 50-029-22363-00-00 193-059-0 N SPT 8676 1930590 3100 339 3454 3311 3267 60 60 60 60 REQVAR P Sully Sullivan 3/22/2025 2 year MIT-T to MAIP (3100psi) per AIO 4G.005 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P1-21 Inspection Date: Tubing OA Packer Depth 227 236 235 236IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250323085116 BBL Pumped:3 BBL Returned:2.9 Tuesday, April 22, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 9 9 year MIT-T AIO 4G.005 James B. Regg Digitally signed by James B. Regg Date: 2025.04.22 15:16:52 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 19, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P1-21 PRUDHOE BAY UN PTM P1-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 P1-21 50-029-22363-00-00 193-059-0 W SPT 8676 1930590 2169 1979 1985 1978 1977 201 395 383 379 REQVAR P Guy Cook 4/3/2023 2 year AOGCC MIT-IA per AIO 4G.005. Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P1-21 Inspection Date: Tubing OA Packer Depth 641 3522 3326 3302IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230402112150 BBL Pumped:1.7 BBL Returned:1.6 Friday, May 19, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9MIT-IA per AIO 4G.005. James B. Regg Digitally signed by James B. Regg Date: 2023.05.19 14:23:46 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P1-21 PRUDHOE BAY UN PTM P1-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 P1-21 50-029-22363-00-00 193-059-0 N SPT 8676 1930590 2169 825 3510 3373 3337 38 36 35 35 REQVAR P Adam Earl 3/3/2023 MIT-T per AIO 4G.005 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P1-21 Inspection Date: Tubing OA Packer Depth 163 162 160 160IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230306132257 BBL Pumped:2.8 BBL Returned:2.8 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 AIO 4G.005 James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 15:34:30 -08'00' MEMORANDUM TO: Jim Regg 2 e. G-/11( Az -I P.I. Supervisor 1 FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 5, 2021 SUBJECT: Mechanical Integrity Tests Hilco,p North Slope, LLC P1-21 PRUDHOE BAY UN PTM PI -21 Ste: Inspector Reviewed By: y P.I. Supry ++ Comm Well Name PRUDHOE BAY UN PTM PI -21 API Well Number 50-029-22363-00-00 Inspector Name: Brian Bixby Permit Number: 193-059-0 Inspection Date: 412812021 Insp Num: mitBDB210429044710 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P1-21 Type Inj G -TVD 8676 ' z Tubing 86o- ze6o - z86z _ 2856 - PTD 1930590 - Type Test SPT., Test psi 3250 - IA 355 3570 - 3445 - 3417 - BBL Pumped: I.8 - BBL Returned: 1.1 - OA 89 189 193 194 - Interval REQVAR - PIF P Notes: MIT -1A as per AIO 4G.005 page 1 of 1 Wednesday, May 5, 2021 MEMORANDUM TO: Jim Regg r7 P.I. Supervisor I�f(, 5131 -7,r,4 FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 13, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PI -21 PRUDHOE BAY UN PTM P1-21 See: Inspector Reviewed By: P.I. Sop" -JBP-- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM PI -21 API Well Number 50-029-22363-00-00 Inspector Name: Brian Bixby Permit Number: 193-059.0 Inspection Date: 3/14/2021 i IDSA Num: mitBD62103I4153137 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P1-21 Type Inj Cr TVD 8676 - Tubing 420 - 3537 - 3424 -- 3396, - -�— PTD 1930590 Type Test SPT" Test psi ' 3250 IA 132 137 137, 138' BBL Pumped: 134 BBL Returned: 34 OA 28 29 29 - 29 ' Interval REQVAR P/F P Notes: MIT -T as per AIO 4G.005 Tuesday, April 13, 2021 Page 1 of I MEMORANDUM State of Alaska TypeInj I G "TVD Alaska Oil and Gas Conservation Commission TO: Jim Regg P.1. Supervisor �� �I Ip I Zwza DATE: Wednesday, March 17, 2021 SUBJECT: Mechanical Integrity Tess Type Testj Hdcorp North Slope, LLC ITest psi PI -21 FROM: Brian Bixby PRUDHOE BAY ON PTM PI -21 Petroleum Inspector _ Notes: MIT -T as per AIO 4G.005 ✓ Sre: Inspector Reviewed BE. P.L Supry-i� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P1-21 API Well Number 50-629-22363-00-00 Inspector Name: Brian Bixby Insp Num: mitBDB210314I53137 Permit Number: 193-059-0 Inspection Date: 3/14/2021 Rel Insp Now: Packer Well I PI -21 TypeInj I G "TVD PTD 1 1930590 Type Testj sPr ITest psi BBL Pumped: 1 3.4 BBL Returned: Interval ODER PIF — _ Notes: MIT -T as per AIO 4G.005 ✓ lepth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8676 Tubing 420 3537 - 3424 1196 3250 IA 132 137 137 133 — 3.4 OA 28 29 - 29 29 P Wednesday, March 17, 2021 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 26, 2020 SUBJECT: Mechanical Integrity Tests Hilcolp North Slope, LLC P1-21 PRUDHOE BAY ON PTM PI -21 Srr. Inspector Reviewed By: JVP P.1.Supry J�— Comm Well Name PRUDHOE BAY UN PTM P1-21 API Well Number 50-029-22363-00-00 Inspector Name: Guy Cook Insp Num: mitGDC201021134227 Permit Number: 193-059-0 Inspection Date: 10/212020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PI -21 _ Type Inj N ' TVD 8676 - Tubing 406 1 2790 - 2628 - 2596 " PTD 1930590 " TyW Test SPT Test psi 2169 IA 620 - 708 717 - 716 BBL Pumped: 1 1.3 - IBBL Returned: 1.2 - OA 167 "~169 170 - 170. Interval OTHER P/F P Notes: MHT -T per Sundry 320-183. Testing was completed with a Little Red Services pump truck and calibrated gauges. Monday, October 26, 2020 Page 1 of I MEMORANDUM TO: Jim Regg P.I. Supervisor���tln FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 26, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PI -21 PRUDHOE BAY UN PTM PI -21 Sre: Inspector Reviewed B P.I. Supry.J Comm Well Name PRUDHOE BAY UN PTM PI -21 API Well Number 50-029-22363-00-00 Inspector Name: Guy Cook Permit Number: 193-059-0 Inspection Date: 10/21/2020 - Insp Num: mitcoc201021134558 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PI -21 Type Inj N • TVD e676 'Tubing -5-o9 27s2 2690 2666 - PTD 1930590 " Type Test I SPT Test psi 2169 to 501 2751 - 2693 2668 " BBL Pumped: 2.9 "BBL Returned: 2.9 - OA 167 216 Interval OTHER P/F' P ✓ -- — Notes: CMIT-TxIA per Sundry 320-183. Testing was completed with a Little Red Services pump truck and calibrated gauges. Pos�"�A-cam s�uee� Monday, October 26, 2020 Page I of I MEMORANDUM To: Jim R� c� ¢/I7i'1 y P.I. Supervisor `""/ FROM: Lou LaubenStein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 17, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. P1-21 PRUDHOE BAY ON PTM P1-21 Ste: Inspector Reviewed B�y:��p P.I. Supry 059— Comm Well Name PRUDHOE BAY UN PTM PI -21 API Well Number 50-029-22363-00-00 Inspector Name: Lou Laubenstein Permit Number: 193-059-0 Inspection Date: 4/9/2019 Insp Num: mitLOL190409123519 Rel Insp Num: Packer Depth Pretest Initial IS Min 30 Min 45 Min 60 Min PTD Weld Type ld TVD nr'e Tubing 1485 -� z4ss as, zass YP J BBL Pum ed: 1.2 "BBL Ret Test : 'iry - Ip JG 1071 1sv �aoe 1v3os90 -Type Test sPT p ui OA 107 - uo ios Interval REQVAR P/F P Notes: Test per AA 4G.005 requires an MIT -IA every 24 months to maximum injection pressure. Wednesday, April 17, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg/<7��DATE: P.I. Supervisor � l'v 41, z/ i 9 Tuesday, April 9, 2019 SUBJECT: Mechanical Integrity Tests l BP EXPLORATION (ALASKA) INC. P1-21 FROM: Bob Noble PRUDHOE BAY UN PTM PI -21 Petroleum Inspector Sre: Inspector Reviewed By: -� P.I. Suprv_� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM PI -21 API Well Number 50-029-22363-00-00 Inspector Name: Bob Noble Permit Number: 193-059-0 Inspection Date: 3/23/2019 - Insp Num: mitRCN190324140415 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 6U Min Well PI -21 -71 Type Inj N 'TVD seta Tubing 62 3661 3509 ',466 PTD 1930590 TYPe Test spr Test psi 3100 - IA z z BBL Pumped: I 42 BBL Returned: 5.5 OA 262 27 N, Interval I REQVAR IP/F I P Notes: MIT -T, AA 4G 005requires two year MIT -T to max anticipated injection pressure (3100) Tuesday, April 9, 2019 Page I of 1 MEMORANDUM TO: Jim Regg � 3/ q P.I. Supervisor Y� FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 26, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. P1-21 PRUDHOE BAY UN PTM PI -21 Sre: Inspector Reviewed By: P.I. Supry Biz - Comm Well Name PRUDHOE BAY UN PTM P)-21 API Well Number 50-029-22363-00-00 Inspector Name: Bob Noble Permit Number: 193-059-0 Inspection Date: 3/23/2019 Insp Num: MARC1,1190324140415 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PI -21 ''Type Inj 'i N TV 8626 Tubing 62 3661 3509 3466 PTD 1930590Type Test! SPT Test psi 3100 IA 2 1 — 2 2 — 2 BBL Pumped: 4.I BBL Returned: 3.9 OA 26 26 22 26 Interval REQVAR _ P/F P Notes: MIT -T, AA 413 005 requires two year MIT -T to max anticipated injection pressure (3100). Tuesday, March 26, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 1 DATE: Friday,May 12,2017 TO: Jim Regg 5Th P.I.Supervisor h,ql /S- ( /7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. P1-21 FROM: Bob Noble PRUDHOE BAY UN PTM P1-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.P.I.Supry IA4- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P1-21 API Well Number 50-029-22363-00-00 Inspector Name: Bob Noble Permit Number: 193-059-0 Inspection Date: 4/30/2017 Insp Num: mitRCN170430142059 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8676 ' Tubing1384 1384• 1390 ' 1384 Well � P1-21 - Type Inj W TVD , PTD 1930590 Type Test, SPT Test psi 2500, IA 682 2695 - 2624 - 2609- YP BBL Pumped: 0.7 • BBL Returned: 0.9 , , OA 286 436 , 432 430. Interval REQVAR P/F P ,j Notes: AIO 4G.005 post cemented IA with shallow packer.MIT-IA every 2 years to the maximum anticipated injection pressure of 2500 psi. SWOP JUL.: 1 , . i+'. Friday,May 12,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Monday,May 01,2017 ti P.I.Supervisor k ? �� 47 SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. P1-21 FROM: Chuck Scheve PRUDHOE BAY UN PTM P1-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Tea- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P1-21 API Well Number 50-029-22363-00-00 Inspector Name: Chuck Scheve Permit Number: 193-059-0 Inspection Date: 4/25/2017 Insp Num: mitCS170425120337 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P1-21 Type Inj W 'TVD 8676 - Tubing l 1379 1380 1375 - 1379 - 1378 - PTD 1930590 - Type Test SPT Test psi 2500 - IA 419 2690 • 2627 - 2589 - 2552 BBL Pumped: I -iBBL Returned: 1 - OA 191 364 350 - 345 - 334 Interval REQVAR P/F F Notes: Tested per AIO 40.005. v SCANNED AUG 2 3 2UI7 Monday,May 01,2017 Page 1 of 1 • . Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,April 30, 2017 12:39 PM To: AK, GWO SUPT Well Integrity;AK, OPS GPMA OSM;AK, OPS GPMA Field O&M TL;AK, OPS LPC DS Ops Lead;AK,OPS LPC Board Operator;AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS PCC Ops Lead;Wallace, Chris D (DOA); Burton, Kaity Cc: AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R; Worthington,Aras J Subject: OPERABLE: Injector P1-21 (PTD#1930590) Post Remedial IA Cement Repair- Barriers Confirmed All, Injector P1-21 (PTD#1930590) underwent a remedial IA cement squeeze on 01/03/2017 to repair a production casing leak at 7,652'. The well passed a witnessed MIT-IA to 2609psi on 4/30/17 and a witnessed MIT-T to 3,793psi on 1/18/17,confirming two competent wellbore barriers. AOGCC administrative approval 4G.005 for continued injection with a shallow packer was approved on 02/16/17 . The well is now classified as Operable. Plan Forward: 1. Slickline: Set TTP,AOGCC witnessed MIT-T—Pass 2. Operations: POI -Complete 3. WI Projects:AOGCC Witnessed MIT-IA after stable injection- Pass Please respond if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110N8 a . .4 2 i i 1. Cell 907-980-0552 SCAI Harmony 4530 1 � � • S O I 2 1 C - - a- a- M a- a- a- r ~ T 4/4 cr . <� Q 0_ ci, _C WrWY CO T @ O N W O ~ u 0 yE 713 > r CO J Z N N @ O �n N Q ,S' 0v a Q 0 C C T 0 0 @ C @ @ O w ) (0 Q v 0 J C7 , r-- r- r ^ t v o a m Q N 0 c s + p v O Id cC c6 (0 Q -6 N L J -) LL LL 2 2 2 2 2 Q c v c to O 0) Cf) 00 O O 0 @ ++ G Z _:'.: .. M N N N M U 75 @ p 'C-' Z Q N > 73 v - 0 C te I- I- @ QJ -O ,n U C >_ U 0 0 0 0 0 _J _l 0 - C �F 02 W- W W W W W W W W v, (1) 'L- ".,.. LL LL LL LL LL LL LL LL LL a.) J J J J J J J J J O _a > Q w O 0:. O Z Z Z Z Z Z Z Z Z (U a) iLL LL LL LL LL LL LL LL LL CC C f1C - U N N C N @ y., > '-, 0) E C) @ Cv s O _0 U a v a) 0 Cr0 c p m > o.�.. r - N r'D TuY U C > U a1 Y+ . O L u M c > Ce I- I- F > Q v a c a 0 R1 , w > J • LL @ 2 2 to w is Q .5.. 0 d' z LL u..ce > U U d N C) ,c w H ° 0 0 W to rn J aC) .� V "'+ L. m N d = m m > = F O __ i = Q a E ° ° U • 1,- � U � �", W y C7,4 v04Kgr: ° 1 O p4 "• e(13z --3 ea 1 al O▪A ' u G~. J O J O J O 1 411t)11/1 ,-...,119 1 40lww >- Q Q Q Q Q D V9C 2 m m m m m m I- , < ZWWWWW WZ O Z E x Ox x x x x < C 0000000 , E 2 W > > 7 > > > Z 1.110. + eeCCL W - Q Q a a 0 0 0 `, c o U Q N rOA V L X N p O - N 00 )n N )Y) N V_ r _ Il) CO •R1 p O 0 0 M O 0 0 N eta cT W N C/ 0 0 0 0 0 0 0 0 0 E o o o 0 o o o 0 0 LI • ' p al Q W Ce 0 Y 0 Q Y Y > ago Q 000000000 @ CC 00. O m t O U co O O O O O N _� O O O O O O O O O Q h N 00 O N M 00 15 _{ 0) t0 CO N (O O 00 f0 f0 ._ E m IR \7 • CO h Cf) M M M CO M 0 M M N N N N NNNNNCNINNN in C 6) 6) O) O) 6) O) 6) 0) 6) C 0 NNNNNNNNN (aLn Q) O O O O O O O O O L C v O O O O O O O O O Y Y 0) co pp C '-1 G V) Itu) U) U Q ) in u) u) In al d W =r1S E C) bA o rn CIDW U g CC N U 75 13 d e z }3 ea ', O •a N In 00 N N m M (L 1' N CO O O O @ H U J m � a < = N � � aori > � � a E z tyvv Z N - m U a = ~ 1� Ct.,. co L Q d 111 c @ et m OCOD ata �- • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Friday,April 14,2017 P.I.Supervisor 0 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. P1-21 FROM: Bob Noble b 'sf\ 1`\ PRUDHOE BAY UN PTM P1-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry t.4:_ 3. NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P1-21 API Well Number 50-029-22363-00-00 Inspector Name: Bob Noble Permit Number: 193-059-0 Inspection Date: 4/11/2017 Insp Num: mitRCN170411152215 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well , P1-21 Type Inj 1 N TVD ' 8676 ?Tubing 269 2266 2200 2184 PTD ; 1930590 Type Testi sPT Test psi 2169 IA 0 0 0 0 BBL Pumped: 2 BBL Returned: 2 OA 19 20 19 20 Interval REQVAR P/F P Notes: AIO No.4G.005,MIT-T every 2 years to maximum anticipated injection pressure or 2000 psi. Friday,April 14,2017 Page 1 of 1 • • Ln O a 1— >, LL 0 — — rr ° .0O nN V1x � t.0)—Lu (..DNp CJ a-^ ' 7 OZ O to O• L + <CV) 0 z U N > O E a c E c O v > CO +, L_a 'C ++ 'O F O 5 a Q Q o u , a O _,--, lW7 0 L a) 0 6 m • C J ' - . LL .z C L to In wF W N N ti O a - U -O a3 O Z K• H O a) > -p a) '7 z O c N FCO N N O C L N L W 0 0 0 0 0 tin c p 0 W W W W W V O L H LL LL LL LL LL U J J J J J a s > +' w Q Q Q Q Qcu 0i cn a Z Z Z Z Z a a a) O a) • fl LL LL LL LL LL K C > U+.+ > CCU a) _▪ c O _0 C: E a u o t. z N a „,,CO u a) a O c O m — U { F- ~ ~ E > u a) 0 C = _0C I20Urn Q C a0 E0 a al K U V) V) J I— ES bkZ W 0LL2 Q, 42 c Ow Ill LL O y \ TS V Eco J ce d J co = E. O C' ', a) a) 0- cc V 00 U u, E E 01 4) (Av 0 a) 0 c 0 RI its co ,4, O )., a G r r' V d O J J O J 4 cc.. g 2 zap � 2 � � 3 � W E •�r "rifO W 2 • m m m m z hU0000 ket D 0 o c) F a) Z > > > > Al= CtCCCLW j +r O. a 11 d LL C O CI C a W wCI N M O o X O O NU co o O oc Y C v 0 N 0 Y a) Q WCD c) 0 E (..DD OceO (JLLOA v (13 CT `^ cc 00000 >c0 ro o W 4o o +' U C t ch oQ 0 0 0 0 Q ) v + D Cr) N N ++ > I0 C) N y_ M Q N N N � N p, N N N N N 0mC n Q O) O) O> O) O) C O Q N N N N N ea , ) Q1 = 0 0 0 0 0 L C Y a) N N in in In 0. 'O m =r) u CM ! O 01 E a) O 2 70 is 9 E Z rz ? o Z N M a Wcp aY+ E Ol IFC9a rtLf N M co 0 u J N J r ' n, Q O N J a CO r/) C O H Z H 0 _ = i 5.- w C -, ca „ a {/L ,i u p La GJ O L P Q 511 I: L CO a 0 CO2 o a s m STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well II Re-enter Susp Well 0 Other:IA Down Squeeze IA 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 193-059 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service El 6. API Number: 50-029-22363-00-00 7. Property Designation(Lease Number): ADL 0034622 8. Well Name and Number: PRUDHOE BAY UN PTM P1-21 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11525 feet Plugs measured feet true vertical 9202 feet Junk measured 11432 feet FEB 0 12 f117 Effective Depth: measured 10847 feet Packer measured 10874 feet p� llU true vertical 8654 feet Packer true vertical 8676 feet q�O/ CC Casing: Length: Size: MD: TVD: Burst: 3� Collapse:l Structural Conductor 80 20"91.5#H-40 44-124 44-124 1490 470 Surface 3979 10-3/4"45.5#J-55 41 -4020 41 -3550 3580 2090 Intermediate Production 11477 7-5/8"29.7#NT-95 37-11514 37-9193 8180 5120 Liner Perforation Depth: Measured depth: 11032-11042 feet 11050-11090 feet 11102-11112 feet 11124-11134 feet 11151-11168 feet 11170-11190 feet 11191-11251 feet 11271-11361 feet 11375-11400 feet True vertical depth: 8802-8810 feet feet 8816-8848 feet 8858-8866 feet 8875-8883 feet 8897-8911 feet 8912-8929 feet 8929-8978 feet 8994-9068 feet 9079-9100 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 34-10954 34-8739 Packers and SSSV(type,measured and 5-1/2"TIW HBBP Packer 10874 8676 true vertical depth) 4-1/2"Camco TRCF-4A SSV 2224 2171 12.Stimulation or cement squeeze summary: Intervals treated(measured): In IA:2376'-,0630. SCANNED ,; i'' , 4 7i1 i Treatment descriptions including volumes used and final pressure: 554 Bbls Diesel,270 Bbls 15.8 ppg Class G Cement,49 Bbls 60/40 Methanol/Water,31 Bbls Fresh Water,4007 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 4614 3261 509 680 675 Subsequent to operation: Shut-In 10 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ® WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-437 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature �'`'� ��—� Phone +1 907 564 4424 Date 1/30/17 Form 10-404 Revised 5/2015 4e ON(/ ` D'�1S 1 rV 31 � RB ' l� - 3 2017 Submit Original Only • • p Well: P1 -21 BP Exploration (Alaska) Inc. Michael Hibbert, Well Integrity Engineer Post Office Box 196612 Anchorage,Alaska 99519-6612 January 30, 2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well P1-21 (PTD # 1930590) — P1-21 PC Leak Cement Squeeze — Explanation of Work Execution In July 2016 a Sundry was submitted for well P1-21 for approval to cement the IA up to 500'. The procedure was sent to the slope and was placed on pending status awaiting the approval of the sundry. After several communications with the AOGCC a new Sundry was submitted in August 2016 requesting approval to cement the IA up to 6900'. This sundry was approved on 9/15/16. The job was moved from pending to active and was executed with the original job scope with a higher cementTlhe job was executed on 1/3/17. The SCMT was pulled on 1/18/17 showing a top of cement in the IA @ 2590'. The AOGCC was notified via a phone call to Victoria Loepp on 1/30/17 and this explanation was requested a submitted as part of the 10-404. If you have any questions, please call me at 903-5990. Sincerely, Michael Hibbert BPXA Well Integrity Engineer (907) 564-4351 • • • O w- CO o a) ° 0�0 O co Lo 00 c3) _°O O U V 0 0 -I LC) 0-) E Sao 3 t 0 (Ni N H %f) 0 o O N O . i— �O ` > cn II in "p CO � _0 O n_ Lu o rn HOco S rn¢ o > ca nQooa <° N Eta 2 ° �_�_ Y i_ ° �_ Q Olio m Lc) 1- ZU 0 N in -v; a 0 m IC 0-= ° `° -0 ft 2 O _ H 3 Q Q E t c HZ tl O co Z coo c = °� ° - 06° -C - CO. o p m �_. - Co ch �c wi_ 0 . J 0) (nm a) Lo m - c a) 3 vi °oip MC Z a } a . a N • �' U) Cl) C C o N c' .. = m = 0) O Q Q CO II c X N ° ' o o N n o Z _1 0 o � I < Co C _Z.a o f o * c o 0 -0 co t c D -� Z � 0 0) Q u) 'E � o c � � oQ a) Q aN M N C C a _ m2U H N o. co 3Q ° .c 3 N N E E W .c O 4- Dto 1_ I- Q w o MIxoa c E a) c nU a- � HLU25- 0 D c a) � Ho) v � O E H N oU m � pU W H ODo > •- c � � 3U a) a) a N. -a a O N >- Z W N O a H 5 w .12 �J o_ Iw - -aQU (1) t Q - a) N N m i 4, I- � � rn = OQ •Q ctH c�iNw � L ° ° a) � co a-a) E co -0 ai cow 03 CL < Lu e6 '" H � DZ ca = aim) c 0 O * Nw 0U) N n_� U -a u) EJ � 2m Jx- C� _ Y D Et2 o 0 - NO2 p5 * aOi = a) c ai E ° Qrn o tY F' D cn- a II Z U U � Q w a) u) > o m II - Co o-- z c" 0- Q-V n • w t Q O. cn *w = viUQ 0 aU o -ocn o Q43 -� w u) ` Zhao a) ten O U H < _ a Z 1.1-1 —'92 _ ° a) 0 D � a) u $ cn c ° * Da co a O � a) c = H a) Eco , o1)- (7) o o � wacr) N 0 Z c � O2 cam i:)- -7_1" O E ,rccn E ,� n_ CIm Nmow II w H pJ E `. C n_ `O X a) 06 •0- -, a) N .Ziac o EN 0 Q � Z a Ct � D Zr) Z W c S cu OIC c 'c Q O ao OM° Coa 1"E' (+6: E a) CO o ° 'E O - cn11 co - a) > cn > c O W ui OH w u) � . - s � II v • N � 1 c) a) c2a .Sa C CL (7) -I _1m z = Q _o in or) • o _o O2 a) a I- H * a) U a) o) O -0Q Z co 2m0OU > H Ci) N n- Ncn ca . o ,-4,-60 N- - a) a) C 0 a) C C‘ Q P U LL U (n J II N = O a) o m C U o > c m +' co a 3 a) �+ �' Z a0 (n Z - Z O L j M O !Z .0 H Q) = 0 p _0 mo ° Q N c�A fl.. u.. O � 'C OO ro) 0, °- 5E 5 E N •� T. fd v � 41 ixmx- - -° aE) a°i a) ° o � CO d Oce II i[) Z � w - aO E E (131- N ° c II U n.I- c -� OHON U 0- u) a) cOO 0 wu_i cn oZ � w a) o00 ooii U .2 cU o - OQ3. .O_� c_o * Zm2wQm oowHaI- ccovcf) m 5-:2 1-_ c * cOr) -0ro a`) '- o� c `nao ° m . HJ 000 I W I) a `� p 'C � cp ( E • Oa � (.Linc) O = • reC > j CN � 71- o a ZQDZ0QHH 22111 E E O OtS � u) a O c \ .- - O OL n_� Q O = a, 0w = a (n � Qcocncno � a) • O II o -§ °' � -) 3 u' w � c _o E E 0 - 0 0 W Z 0 C<"0 II - c) j � > N c � H o o O U v w ai a) m e in a c`� o Ca 4I- 4a � Jm II a. CO.. II a) - H � II ° - U � N � _0 - = a N a Ivo _a . U wU = CL jO � z_ -) * N = O o"•- cnn QQDEt c0 > o . .a cin ocam) c�`o .� o * U) 02 � u) u) Q (� * H Qn-liH ca_ n_• ncnH 2 UM : HQ « Ua. _c la oNI- _1 o : w i- < co co co co p '- I - r� N O O C N N N O co O H co co r- V N N N N N N CO P O O O O .- = U Q • • * o LO 017 a) a) -p co > U) a) N O a a)C > U) H n-0 < 0) •F O ° Z * c W C O_- _0 W ti Q CO 0 a) . - - ° M g � ai xoi •- C o � (7) in co co E E N �. U p - o in co E O M aa)) N as - ca co U 0 co Q Q n. � H ,. I � - o o E ID a) o N (6 •O ' L o CO d. cnoQ 0) _ 0 s � rn a) ami p a) O Q.� `-' 17 N a) co N co Q co 3 4) N N Cr) C a) E ri H a) O a) 7 C * Q 00 �O LL C a) °.. Q 7 CO U O = CO H c 7 oEDN CI- a) Nen _0o ai Cr) rn.- -00 Cl) N d 3 C > O Q N co 2 O c o °-- - ° - c a) +. - M a) O N a) = 0..° a) -a C c m o o 2 E o a E Tv' U) Eo o .� ,-. Qo o - G a) o a) N c co o •_ U .., c''o iv E 0 N p .c o > 7 a) - V) Z ... N c M E in C CsI v-, E ao E Y m a * o o U U Q o 0 7 U 45 E aa) ami co 7 3 d IV CL L - ° -Q O L '-' .� No N- O < -d ° j }' m ° H N 02 .§ o cyan ,-,ccs a o Q-a - cv rn N a)T. i = U o o c a 06 ° 0.1_ c � � m *�. 3 Q O of U c ( o O N O O0 3p I-- * . . 00 - v .. 0 ° w � E a) co U o ~ " X U) Q co E o a) Y p cn 3 w N E 2 a (A U 3 0 09 OH Qo 0co CC0 E N N �� o 0 a0i n co c (7) u) so Uao < .cp U E a) -0-: , O m- � o c Y o 46 < < * tch m : n = Q � n * - o moo - U ° � E (� � m � _ * � Q N � � 2 * d 3 * c E O c -am � H U uOi Dm * - o = F_ ai c a '1) ai v 3 3 a) U Z •.° a) OW =W c� o cn c° r� . a) CO to a•_ Z' o a) Q o ; = -0 -2 * p ° WE - ° 2 ,_ CO ° O >U U a) CD ° cpm D c0 CO J Q co - ix 0 17 (p N c Q tN Q > L >O 7 m ..' = a ) - ° " m Q Z ~ O O - � Nom - (n a) ° 0 � a) � O _a w - •� w W 7U ca) � J - w u) - _ >t= O N L 0 II .- - C a3 �_ ao O C i II - ,tv n Ai - aH ° o EI-- o = ao - a) c � o � , 2Q _ �� o QUA _07C) 07 Q O O 0)04-- _c a) . _c N > ' Occ ' 1 o 'o a 3 _c � m - Q' - J - a) O o a)CL C - rx ._ I— .N -- cn2 — _ -o Cl) Z = o .= H U) ° - a) * ZmZI- o up U — U * a 0 E .N- u°ia) na�i � Cn2 ° Cnp E � 34,2 � � U � � oac° OMN O - > co Q cn ° r� ° c 4- N- - -0 .-. c H c H ° m >` M C c Q L 3 3 N > c`) C ..... () as U N N a) co N > D E d > . i_ O UW 3 .0 r 2 0 co it c a) H0 7 c tt L .0 a) c co N a) U ° J U H o a) ° aa IL 0w CDU ,_O n ° co o _ vD c o 30 E .- c 4-E' 4t ow � 0 °O , c. * L.; OH * m - N a) In UH o - VU H = r - Eo - oUHoa * * * -- � * * 0) .EU * 0_ H O_'5 O_ : U � 2 : * U = cci E o2 : U -3 = .*k I' M H Etc N- r•-• i'-- I,- r-- ‘- - - - - - - - - CD 0 0 0 0 0 0 0 0 N N N N N N N N N CD - Cfl r� - r - - - - - - - 0 ai o r- D o mo T (°(D Uii o w ) 13 L'u z — — co Q U d -Q z o c 0 _ �� Cr) Z N _•` a o O -o C LU LU (6 O Q - N 2 Q ° Q� Z OC O - Z N co c�0 a) c m o _ U z �� � � ° C) in 0 Q a) „:„D- 0_ o0 o ND Z - 0 0 0 '� T P00.). -(5 O oO o I H U �Q -0 0) c a) c) TH C Z D0 N W o Z M � .c �(J�J� 0 1 o m 'Lii (1 C1.o oU o —` y �0 Du_ L c JJ WON 6) = 0 M W N N LL -p N u' O N Un NEM W >, g' F' a°)i 0z 01 Z c7n Q W rn o •c O o °' Q ° _ m 0 (1) 1- W ELD 1- O d CT v Uj Q L 2 Q o �M �� W s, _ z Z -6 C� Z 0) � c•`i acZ in cr)-- .5 W © wrH © HL moCT --,- LL. M x- d = aa)icco2 oIoD - � pW wOOQ0 2 `tr �r ° O W pZ 3 D t O < E H WomcM _ mD_ EHF-_ 0O * a) ° v wu- D a o z > W U o 1 O m * O_- (-) W M ° 4 Y �L0 rn a) o Z H_ , 0 ti : 0 ID >- 0 0 W * g 2 U Y rn o w oN Z i 2 m a IT a Q app : _ w Et Et = CJ N Q u) Q O ��011 F- u) f 2! 0 W a r- T Q... m oo m LU C3 C N ne 2 UA H U) V> Z v- 65 } Un p o LoN = D Z 5 Tp W HJ — Hw a5 - 0) Q rn EST Jp a) � � g � ©a � O � OaZ � � 2 � ° H w m � ° D actFv < U, OHZ0dmJz0CDOOz -0 NT cNoz ? iaO Ur75 CD m � � m � DHZpX1YW 102oc Y - N po > Wr l— O W Z = ZZ U) u) I3DQHO > Wd600p 0dc/) c '•— Mowll m a WpzH � � H � � N � � IL X � d � U m � � v � = U Z Zml- OWcn = OCD W0 = ZZWmoZ � " tCWHo J 15 Cilfw - QCD> o c 00 -- 55 __ p2 � 00u) F00UnZZ � 0 F- � 73 = 00 _ g1 Ill ; Nr (nwwmJ : E- CD d co ID O m E- E- _J UA : : CC 0 0 d « : o F- a l>i : d : O coo V- Li Y co_ 2 N- r- r N- T T 0 o O o C/) N cV oM N N N N o CD M r- T CO o CO N- CO CO 6) m (0 T N M (p N `--7. T T T T T T _� FMC 411 WELLHEAD= CSN SAFETY NOTE TBG HNGR FMC BPSH @ 34'MD. ACTUATOR= AXfSON -2 1 ***CBL RUN 05/13/93 IS 22'SHALLOW TO THE KB.ELEV= 50' OPEN HOLE REF LOG RUN 05/05/93.IN THE FUTURE BEV= USE JEWELRY LOG OF 7/18/03 FOR TIE-IN*** KOP= 1289' Max Angle= 46"@ 3367 Datum PA)= 11097 M 2224' —14-1/2'CACO TRCF-4A SSSV,13=3.812" Datum N 0 D= 8800'SS —2376' HEST TOC N IA(01/03/17) 4. 10-3/4'CSG,45.5#,J-55,D=9.953" H{ 4020' i 1�1 I/ •� GAS LFT MANDRELS 111( 14 ST MD ND DEV TYPE VLV LATCH FORT DATE 1111 1111• *1 4872 4165 43 T -TMPDX BK 11 11 *2 10737 8568 39 TE TMPDX BK Minimum ID =3.725" 10929' .. ►111 "STA#182=BEHIND CEMENT 4-1/2" PARKER SWN NIPPLE 111 Q.. 10816' I-14-1/2-PARKER SWS NP,D=3.813" '1•1 �•• 1 ♦1 4-1/2"TBG PUNCH(10/16/16) 10826'-10830' i•i 1j1 Z �—y--- 10874' —17-5/8"X 4-1/2'TW I-BBP PKR,D=4.00" I ' I 10912' --14-1/2"PARKEIt SWS NP.D=3.813" ' r 10929' H4-1/2"PAF KER SVVN NF',D=3.725" 4-1/2"TBG,12.6#,L-80,0.0152 bpf,ID=3.958" —1 10963' 1 - s 10954' H4-1/2" WLEG,ID=4.00" 10959' H ELM)TT LOGGED 07/18/03 PERFORATION SUMMARY RET LOG:DPWNE1,YDENS ON 05/05/93 ANGLE AT TOP PERF:37 @ 11102' Note:Refer to Production CB for historical perf data SIZE SFF NTER/AL Opn/Sqz DATE 3-3/8" 6 11032-11042 0 09/23/04 3-3/8" 6 11050- 11090 0 09/23/04 3-3/8" 6 11102-11112 0 02/05/94 3-3/8" 4 11124-11134 0 05/13/93 3-3/8" 4 11151-11168 0 05/13/93 3-3/8" 6 11170-11190 0 02/05/94 3-3/8" 4 11191-11251 0 05/13/93 3-3/8" 4 11271-11361 0 05/13/93 3-3/8' 6 11375-11400 0 07/18/03 lik —11432' --1MLLEDHES CBP(01/10117) PBT) H 11432' 11111111111111111111 ►11/11111111111111111 7-5/8'CSG,29.7#,NT-95,D=6.875' H 11513' DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MC INTY RE MIT 05/10/93 ORIGINAL COMPLETION 10/27/10 RLW/PJC TT DEPTH CORRECTION(7/18/93) WELL: P1-21 08/12/01 mnp CORRB 11ONS 10/18/16 BWJMD SET CBP/CMT RET/TBG PUNCH FERIvIT No:'1930590 07/18/03 3JI tL/TLF ADD PERE 01/05/17 MZJJMD C8 'ITID IA(01/03/17) AR No: 50-029-22363-00 06/25/04 RAP/KAK PERF CORRECTIONS 01/11/17 JCF/JMD MILL®CMT RE&CBFYSET FISH Sec. 16,T12N,R14E,514912 FEL 2894.96 FNL 09/23/04 JRA/TLP ADD PERF 10/04/10 RLW/SV SAFETY NOTE BP Exploration(Alaska) • or T . ,b10Iii7;`. THE STATE Alaska Oil and Gas if'110 ,rf ALASKA Conservation Commission 333 West Seventh Avenue r Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 ':"gFax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer SCANNED l'Lb 1 VT BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P1-21 Permit to Drill Number: 193-059 Sundry Number: 316-437 Dear Mr. Hibbert: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED this IS day of September, 2016. RBDMS L. SEP 1 9 2016 STATE OF ALASKA OALASKA OIL AND GAS CONSERVATION comm. APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well I I ' Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Cement IA GZI I 2. Operator Name: BP Exploration(Alaska),Inc . 4. Current Well Class: 5. Permit to Drill Number: 193-059 ` 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service El, 6. API Number: 50-029-22363-00-00 , 7, If perforating: NA.. NO 8. Well Name and Num r: What Regulation or Conservation Order governs well spacing in this pool? E i\(E D Will planned perforations require a spacing exception? Yes 0 No I 1 PBU P1-21 • REC 2 6 9. Property Designation(Lease Number): 14(6 10. Field/Pools: AUG 201 t! ADL 02 '8&034622 a$a9 7- PRUDHOE BAY,PT MCINTYRE OIL • OTS 9' 1 S,�1.6 11. PRESENT WELL CONDITION SUMMARY AOGCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11525 , 9202 • 11432 9126 None None Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 44-124 44-124 1490 470 Surface 3979 10-3/4" 41-4020 41 -3550 3580 2090 Intermediate Production 11477 7-5/8" 37-11514 37-9193 8180 5120 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11032-11400 • 8802-9100 4-1/2"12.6#L-80 L-80 34-10954 Packers and SSSV Type:. 5-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and ND(ft): • 10874/8676 4-1/2"Camco TRCF-4A SSV • 2224/2171 12.Attachments: Proposal Summary IZI Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 13 14.Estimated Date for Commencing Operations: September 15,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG RI' GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Hibbert,Michael be deviated from without prior written approval. Email Michael.Hibbert@BP.com Printed Name Hibbert,Michael Title Well Interventions Engineer Signature N_ ' \�`\\' Phone +1 907 564 4351 Date 8 fedi lr :, COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: ,s -31Q -4-f3-7 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test Ef Location Clearance 0 Other: ,4P p re' V C d A c i o f`Y-L G for- 'f r 0-2v e.d f,h C C f/port ,a Fur- 1VI i '17 ! C v ✓t tt��t� '1 , .c-- ct I,S 1, k. Post Initial Injection MIT Reda? Yes4iir No ❑—/ Spacing Exception Required? Yes 0 No ICY Subsequent Form Required: /6-4.r (j ^ APPROVED BYTHE Approved by: P y. _ COMMISSIONER COMMISSION Date:Qaiev _��4vi-L. 4``5i1 9)42, t'nr_/1c. coy/ ff/d7A 7//3/2olb . ORIGINAL RBDMS (-t- SEP 1 9 2016 Submit Form and Attachments in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. by • Well: P1 -21 P1-21 PC Leak Cement Squeeze Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Kaity Burton (907) 564-5554 History P1-21 is a produced water injector that was scheduled to be converted to WAG/MI service over the next few months. During an injector conversion screening, an MIT-IA failed w/ 0.6 bpm @ 1900 psi. Also, a recent caliper run 1/23/2016 showed wall losses up to 37% at about 593' MD. An LDL run on 04/17/2016 showed a PC leak at 7654' MD and with no leaks in the tubing or the packer. The plan forward is to place cement into the IA to fix the PC. The cement will be brought up to -6900' MD to cover the IA leak and return the well to operability. Current Status The well is currently classified as "Non Operable" by BP due to a production casing leak. The well is currently shut-in until the leak is repaired. Economics Estimates of remaining recoverable oil in the pattern based on offset waterflood only pattern would suggest that we can recover an additional 1 MMBO. This well is being progressed as one of the P1 injector conversions to MI capability. Volumetrics suggest conservatively another 1 MMBO oil recoverable if the conversion to MI capability is executed. The proposed plan is economic and should restore the injector to operability for the anticipated remainder of waterflood field life. Objective This cement job is to repair a PC leak @ 7654' MD and regain operability of the well. Cement will be circulated down CT and up the IA. The new cement top in the IA will be @ -6900' MD. This cement top is the deepest that would still reasonable assure a passing MIT-IA. An AA will be requested to allow this well to be a WAG/MI injector. Post-Job Evaluation This well is an injector so an AA will be applied for to allow for WAG/MI with the following proposed evaluation criteria: ➢ MITIA and MITT to maximum anticipated injection pressure ➢ SCMT to confirm Top of Cement (TOC) • Temperature Warmback Log & Water Flow Log to verify no flow behind pipe Long-Term Integrity Monitoring ➢ Record WHPs and Injection rate daily. • BPXA will submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report. • 2-year (biennial) MITTs and MITIAs to maximum anticipated injection pressure. ➢ Maintain IA pressure belo•000 psi normal operating limit. ➢ The well will be immediately shut-in and the AOGCC notified if there is any change in the well's mechanical condition. ➢ After the well is shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 2 TREE= . FMC SA.NOTE: TBG HNGR:FMC BPSH @ 34'MD. - WELLHEAD= 01W • ACTUATOR= AXELSON P 1 2 1 RUN 05/13/93 IS 22'SHALLOW TO THE - OPEN HOLE REF LOG RUN 05/05/93.IN THE FUTURE KB. ELEV = 50USE JEWELRY LOG OF 7/18/03 FOR TIE-IN*** BF. ELEV = KOP= 1289' Max Angle= 46 @ 3362' I 2224' —I 4-1/2"CAM00 TRCF-4A SSSV. ID=3.812" Datum MD= 11092' Datum TVD= 8800'SS 10-3/4"CSG,45.54, J-55.ID=9.953" — 4020' I GAS LIFT MANDRELS LI ST MD . TVD DEV TYPE VLV LATCH PORT. DATE 1 4872 4165 43 TE-TMPDX BK 2 10737'8568 39 TE-TMPDX BK I I 10816' —14-1/2" PARKER SWS NIP, ID=3.813" Minimum ID = 3.725" @ 10929' 4-1/2" PARKER SWN NIPPLE 23:1 Z\—, 10874' —17-518"X4-1/2"T1VV HBBP PKR, ID=4.00" I I 10912' -14-l!2" PARKER SWS NIP, ID=3.813" I I 10929' _-J4-1/2" PARKER SWN NIP,ID=3.725" 4-1/2"TBG, 12.64, L-80. 0.0152 bpf, ID=3.958" —1 10953' 1---' , 10954' —4-1/2" WLEG, ID=4.00" 10959' —I ELMD H LOGGED 07/18/03 PERFORATION SUMMARY REF LOG: DPRJNEU/DENS ON 05/05/93 ANGLE AT TOP PERF:37 @ 11102' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE I 3-3/8" 6 11032- 11042 0 09/23/04 3-3/8" 6 11050- 11090 0 09/23/04 3-3/8" 6 11102- 11112 0 02/05/94 3-3/8" 4 11124- 11134 0 05/13/93 3-3/8" 4 11151 - 11168 0 05/13/93 3-3/8" 6 11170- 11190 0 02/05/94 3-378" 4 11191 - 11251 0 05/13/93 I 3-3/8" 4 11271 - 11361 0 05/13/93 3-3/8" 6 11375- 11400 0 07/18/03 I PBTD —I 11432' Imummem. 4117017041r titititikititititikOi 7-5/8"CSG, 29.74,NT-95, ID=6.875" — 11513' ',vAvvAVAVAVAvAVAvA,A, DATE , REV BY COMMENTS , DATE REV BY . COMMENTS POINT MCINTYRE UNIT 05/10/93- ORIGINAL COMPLETION 10/27/10 RLW/PJC H DEPTH CORRECTION(718/93) WELL: P1-21 08/12/01 RN/TP CORRECTIONS PERMIT No: 1930590 07/18/03/13JMcLiTLFIADD PERF API No: 50-029-22363-00 06/25/04 RAP/KAK PERF CORRECTIONS . Sec. 16.T12N, R14E,5149.72 FEL 2894.96 FNL 09/23/04 JRA/TLP ADD PERF 10/04/10 RLW/SV SAFETY NOTE : BP Exploration (Alaska) . Post IA Cement Job P1 -2 1 -- att,4.,Iso ,,,16.16:2,„SMALL Mt le t tlik. 0'54$ 'IN Fl.t.otiT OKI; 1 , — ' 1,6,h.,Ofti.tOre LI:, • ' ' , ,'4-os-.- -7771 ' ) I- ' • . ,., . ., , ...... .eri 111f.'",..1,—.10.7* 5;4(7-TOC izi.04.. 1 1 7 ifroiliiii) .:3-71°15-' .4 1197279' '''', PARKER SWNNIPPL,E [ ,., ,,. H -------- _ _ NlIft.git,*(04,Sk.IOW 7, # 7 '1 St*. .F10- i.. r....-,*,..•A.,- X,'r ‘trx.,,4 x,4.,..a 4 X 4 ..' . ,.. V" 1 ' 40.' 1 - , X- !. 1 . ' 4 • ' ,ctfl,0.4;., ,,,, .„ . _.„ fi “ ty .1_, —,,, --- . --1 ! , , OW;'mutt r.:0*0 Pt 7.:A - *,,,, A* - ',*.- , f.c..1,- 'I '` 1 -.... Is,s. 4t-. .4. ......, 1 4 • - : ••* • 1 SAfETY t./VG Hmat t•MC aPS*4 4 34'MO CEI.RuN 051343 6 2 t SHALiCtei TO t t* - , - P1-21 Proposed P&A et 14CLt REF LOG W.,*OS 05;13 tx* T-$4. 4:,'r°,04't - - _SE JEVt E LRY LOGO* - r• *- , i0.4$1 "02'i.litii' 1$41:03+4*x:' 1.g..4.: +4.3:...........4*-,...44' -I Cement Plug#2 Circulated down tubing,through perforations @-1800' • •••••,- .p. -----4 MD and up IA and OA to surface - . 1 - - 1 - -,c-1 1 ... .....4 • tmum ID =3/25" 410929. . . .....: ..... 41?2" PARKER SINN NIPPLE 1 * ...-. :". '. *06:-4 ••- .7. - , ---",', '.T-- Cement Plug#1 Pumped FB or laid in with CT • .. - . - "' 092s H. ;,.. .:-......7-„.ot.-°,;- - '_,4 I •: •:: .:: ... •••••••.•'.....-'.. -.' :' -•1.-* ....gt t .... — 4 1 .4ca- H 1.0957 --- ... .. ..::.:- 4.19 54 - toutottuttmo .•••:. :- • --".--- 10959' a-AC --- t s."-- -. ,.'.. • • • :- s :-... . - •:• % ,,a'!X4 *St..E A--',"PST r 4 -.1- ... .. . ...•...:. .., t... P4- r r.,,1, .1..t.%,"s'00:10L'04 ,30.-4 144. ' ' • ' 7R"., 010 ' 1W 4 5, 4 .- . . . 3 10.4' 4 it IR- 4 . . .•. 4- 4. -^ 4 •• .'.. •: . ' , - - - El IBMS' 1 114 I- tv, , ,t,', , ix*2* 0 0 I 1 ''. ''. '*- '.0' ':- 4." I ''' vi 11513 7 . . . O.' - .. . I 1 Z'2/9 3, ORIGINAL C OR Pt En os - , r 1- - e',1- Ir.-,tf-' '. I 'r -.r7 • 4 1 ' _ 5 • Wel_vvn Job Notes • LLR for IA (PC leak) is —0.6 bpm at 1900 psi. • BHCT is estimated to be 135 F. • BHST 142 deg F. Cement Calculations Cement Job Total cement to pump 103 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours 1 6 Activity • e(hours) Shearing time,quality control,PJSM 0 Cement displacement 3 Cement contamination 1 Safety 2 Minimum required thickening time: 6 Cement Ramp for Blend (1St cement job) Time Temp Pressure 0:00 90 0 1:00 100 2800 2:00 120 3200 7:00 60 2400 Volumes: top Punch volume MD MD Size ID bbls/ft. Ft. bbls 4-1/2"tbg 0 10850 4-1/2" 12.6# 3.958" 0.0152 10800 165 7-5/8"29.7#x 7-5/8"x 4-1/2"annulus 0 10850 4-1/2" 12.6# 6.875" 0.0262 10800 285 1. Set 4-1/2" composite bridge plug in the tubing @ -10,847' MD (middle of the first full joint of pipe above packer). Reference attached tubing tally dated 5/9/93. 2. CMIT/LLR TxIA to 1900 psi to verify CBP set. The CMIT should fail due to the PC leak but the LLR should not be significantly more than -0.6 bpm/1900 psi. If the LLR is significantly higher than this then call Interventions Engineer for plan forward. 3. Punch tubing w/ 5' tubing puncher across collar @ 10,825'-10,830'. Note indication of tubing punch in AWGRS (if evident). If no indication of tbg x IA communication is evident then pump to verify circulation down tubing and up IA. 4. Set 4-1/2" Halliburton SVB squeeze packer (composite, sliding-sleeve-style cement retainer) @ -10,822' MD (middle of 10' pup joint). MIT-T to 2500 psi to verify retainer set. 1. Rig up a micromotion to IA returns. This will help determine if the PC leak is drinking any cement and track the cement top in the IA. 2. MU Halliburton SVB Squeeze Packer cement retainer stinger. RIH and circulate heated (160F) diesel to the stinger taking returns from the CT x TBG backside. From just above the retainer, circulate-130 bbls of heated (160F) diesel out of the CT to displace the CT x TBG backside to diesel for the cement job. 3. Sting into cement retainer. 7 • 4. Establish diesel circuiatL n down CT and up IA to tanks. Verify con backside is Si. Pump the following fluid schedule. Note: Do not pump any freezable fluids (other than FW spacer and cement) through retainer into the IA as these fluids will remain in the IA after the cement job and may end up across the permafrost, freeze, and collapse the production tubing. a. *285 bbls of heated diesel (160F) b. Minimal FW spacer—divert this upstream of the CT so that nothing but diesel or cement goes into the IA. c. 103 bbls cement per design d. CT volume of FW (unsting from retainer w/ last 1-2 bbls of cement in CT) 5. This should put the TOC in the IA @ —6900' MD if there are no lost returns. It is expected that the PC leak will drink little cement due to the small size of the leak. See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. 6. Unsting from cement retainer w/ 1-2 bbl of cement still in the CT and lay remainder of cement in 1:1 on top of cement retainer. Monitor CT x TBG pressure closely as the stinger is pulled out. If the retainer fails to seal, the CT x TBG backside pressure should jump to —950 psi. If this occurs, hold a minimum CT x TBG backside pressure of 1000 psi throughout the rest of the job. This will keep the cement in place in the IA despite a failed cement retainer. SI IA for the remainder of the job. This will leave all of the cement that was laid on top of the retainer to mill later, but will preserve the IA cement job. 7. If the retainer holds pressure then contaminate cement and circulate out or reverse out cement down to the retainer. 8. FP tubing down to 2500' MD as needed. Contingency#1: If at some point cement locks up and cannot be pumped into the IA due to high circ pressures then cut cement at surface, close in IA, and unsting from cement retainer. If retainer appears to be holding then reverse out cement if possible or lay in cement 1:1. If necessary to lay in cement then contaminate and circ out cement to surface. FP down to 2500' MD prior to rigging down. 1. MIT-IA to 2500 psi. Establish LLR if fails. 8 ' Coil • 4110 1. MU 3.70"junk mill. RIH and tag top of retainer (expected —10,770' MD). 2. Mill through cement, retainer, cement and the CBP. Push CBP out of tubing tail amd POOH. Slickline 1. Set TTP. 2. MIT-T to 2500 psi. 3. Run SCMT log from tubing tail to surface to find TOC and relative bond. 4. Pull TTP. j r ,�r,,r//i;i%/�f`/` �^'''.�/'r '"'',v'/'/'^��'i'J�'��1,,+''/1.+'/J!�/!�',/v.�y',�G,%'G1', E-1�[ne /`7f F,rF /'%f i ;rffr;�r l',lrr �`'�'''�y 1. WFL and temperature warmback log to indicate any flow behind pipe. DHD 2. After well is on injection and stabilized, perform AOGCC witnessed MITIA to 2500 psi. Welt Integrity En ineer `k., % ,-�� 1. Add Biennial MITTs and MITIAs to AnnComm for additional monitoring of the well integrity. 9 • 2S eila4ARY19006.7 0518 311193 ,11P1, P1.21 4.1 L-I0 TD8 12-6 *IV Ret.861.10 IF ITEM C CO ' LENGTH TOP BOTTOM 4-1R•v8.80. NSCT BOX 4 00 5 30 .90 10952$2 10953 80 MD PUP NSCT PIN TDS BOx 394 5.56 2,60 1015022 1095242 PUP$1 4-17 105 BAP 3 96 5.56 9.67 10940.35 1C950 22 PLP JI 4 17 ircis 0.AP 3 96 556 9.95 10930 10 1094035 Par16or 45 SWN Nopfei,wo RHC PLUG 3 73 5 23 1.50 . 10926 90 10930 40 PUP .14,4 1,7 1D3 HiP 3 96 5 56 5.90 10923 00 10926 90 PLP J7,4-17 70S 84.P 396 5.56 1 93 19913 17 10923 00 P16,14411-1/7 SwS NIPPLE,VS 3 91 5,27 1.1T 1991104 1491317 PtPJT4-u7T0$84P 3 96 5.56' SU 10901.07 10911 50 KIP JT,4 Pr TOS 86P 3 36 5.54 9,98 10491 09' 10510167; PUP O.4-17 IDS SAP 396 5_54 4.90 10985 99' 10091 991 ' X/0,41tT T06 PftI i Sirr NSOO BOX 3 93 6.25 .90 10455 09 10865 991 T/W EXTENS6CN 4.00, 5.53 5.77 101179 32 10465 09, TIW - PACKER 4.00 6 53 5.05 10674 27 10479 32 TIW LATCH ASSEMBLY 4.00 6 32 1.2$ 10473.02 104374 27 PL1P JT,4 17 TOS BAP 3.96 S.56 1.0$ 10966 97 10473 02 I 414 liT TUBING II 3.96 5 54 31.70 10427 19 10866 971 PUP JT,4-1)7 MS B&P 3 96_ S 56 0.43 10617 34 10327 Ai PAA R 1.17 SWS NIPPLE_ TDS 3.61 5.23 1.37 10415 09 104+7 36 PUP JT.4-1 tr TC8 344 3.94, 554 9.91 10.06 06 1841 5.90 PuP 0,4.147 TDS EMP 3.1NI 5.54 10796.34 - 10006.08 JT 4-1 : 1463 12 .94 554 10756 63 ¶079634 et,J7,4 1,7 TDS BiP 396 554 9 95 10748 99, 10754 63 X4). BIC Box X MS Pr 3 96 5 56 1.91 10744 77! 1C746.64 4-1,2"&W . 1643X GOA w P.,•••Irly 3.83 7.03 7_31 10737 46, 10744 771 XO TDS Box TEM Pir 3 96 554 1.99 1073547' 10737 46! o1JP 47,4.17 TC6 IMP 3 98 554 9,90 10725,57 10735,471 147 T$4.r -1.2-TUBING 134149 396 5.56 5834.04 4891 19 ¶072557 • PUP JT 4,17 TES 396 554 9116 486143 449149 X.O. 13TC Bo.X MS Pm 3 96 556 1.91 4879 72 4881 6-31 4.17 MERLA TMPDX GLM.WO., 3.83 7.03 7.32 4672 40 4*79 72 X.00. T6xBTCPw 3 941 5.54 1.99 4470 41 4072 44 PUP JT,4-lir TOS$&P 3 94 5.54 9.17 40610.54 4070,11 54 JTS 4-1/2-•TUBING P1504215 3 96 5,54 2413.91 2246 63 4860 5-4 PUP JT,4-1fr 106 84P 3 96 554,' 5.15 2240 65 2245 53 FLOW COUPLING 4 liT TDS pen-6 FOX to• alnErll. 223060 240 66 GM=7RCF-4N 3331/ FOX BSP 351 5 34 LS? 2224 13 2230 60 FLOW C:OUPL NG 4-17 TDS oin x FOX bow 11.30 2214 75 2212413 PUP Jr.4-1X TDS 136P 3 96 5 54 5.00 2208 85 224.75 55 JTS 4 17 TUBING .218-1270 3 96 S 56 2172.533& 324 2209 55 RAC TUR1631/4.1643414 KIP 3 96 10.86 2.32 34 001 35.32' POOL 7 R6,4,71,410 T.• •r LOS 34.00 34.06 1111.1111111111 111111 1111111111111111111111111111111111 270 its 4-1/1, 124. 140, 1111.706 Tubing 111111111011111.1111111111111 2 Om Lift hien*** Up twMght 01 tubing string • 190,0061 D459.11 w640h1 64 11$41 155,0000 Stait4•66 Suet Control lino bands • 58 P8T0 . 11432' I 0 • • DRAFT AA BP Exploration (Alaska) Inc. requests approval to continue WAG injection service with an IA cemented to —6900' MD into well P1-21 (PTD # 1930590). Well P1-21 currently has a production casing (PC) leak at 7652' MD which will be repaired, per attached Sundry, by cementing the IA and bringing estimated top of cement (TOC) to —6900'. An initial cement evaluation log (SCMT) will be run to verify cement placement after the initial IA squeeze as well as a temperature warm back and water flow log (WFL) obtained to verify no flow behind pipe. An MIT-IA and MIT-T will be conducted to 2500 psi to confirm the success of the repair and that both the tubing and production casing are competent. If continued operation of the well is granted, the inner annulus operating pressure shall be maintained below the MOASP of 2000 psi. In summary, BPXA believes Prudhoe Bay well P1-21 will be safe to operate pending the successful completion of the planned work and testing outlined in the attached Sundry, and requests administrative approval for continued WAG injection service with an IA cemented to —6900' MD. If you have any questions, please call me at 564-4303 or Jack Lau/Adrienne McVey at 659-5102. Sincerely, Attachments Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Doug Cismoski Lau/McVey GPMA Operations Team Leader Katherine Burton Ryan Daniel 11, • Prudhoe Bay Well P1-21 Technical Justification for Administrative Approval Request July 19, 2016 Well History and Status Greater Point McIntyre injection well P1-21 (PTD # 1930590) has a PC leak at 7652' MD which prevents current injection service. This well is being progressed as one of the P1 injector conversion to MI capability wella. Estimates of remaining recoverable oil based on offset water injection service only suggest 1 million barrels of oil (MMBO), with another 1 MMBO oil recovery if the conversion to WAG is successfully executed. Cementing the IA as an economic integrity repair option, as proposed in the attached sundry, would restore injection service for the anticipated remainder of service life. A SCMT will verify cement placement after the initial IA squeeze. A temperature warm back and WFL will be obtained to verify no flow behind pipe. Lastly, a MIT-IA and MIT-T to 2500 psi will be performed to confirm the success of repair and that both the tubing and production casing are competent. Recent Well Events: > 06/03/14: AOGCC MIT-IA Passed to 2500 psi > 01/20/16: PPPOT-T/IC Both Passed > 02/19/16: MIT-IA Failed w/ LLR of 0.6 bpm @ 1900 psi > 04/18/16: PC leak found @ 7652' ELMD Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A SCMT will verify cement placement after the initial IA squeeze. A temperature warm back and WFL will be obtained to verify no flow behind pipe. A pressure test of the tubing and production casing will be performed to 2500 psi pending successful sundry repairs, demonstrating competent primary and secondary barrier systems. Pressure on the inner annulus is maintained below the normal operating limit of 2000 psi when the well is on-line. Proposed Operating and Monitoring Plan 1. Allow water and gas (WAG) injection service. 2. Record wellhead pressures and injection rate daily. 3. Submit a monthly report of well pressures and injection rates to the AOGCC. 4. Perform a 2-year MIT-IA and MIT-T to maximum injection pressure. 5. The well will be shut-in and the AOGCC notified if there is any change in the well's mechanical condition. • • • + I m o d O H N � 3 CU A 8 II 4m.L • ._ .f._ 'A.k 5E-c.-,A. • 111111 . , SWPD 7 MCFPD ; ..;L:-. , .-- - --, - ,- - m; ,.,- r., ,zi ,..., =1.• +-i ,-,,i .--- , !;..-.; ',.. r '..' -Ws : 8 . 8 , # 8 : .,.. $ . •.? , I t 1.-.P .,.. •7.4 .",..., 4-0 —__, •.;..3 0 — CL , CI — o o 47. 0 , 0 717. C : I . -------- . _., 4L- -.:•'''. 0- ,...:. ,..-. , = CD ii -$ :I Y., .-----3 ,,, •,-.g .,..n , _ . 0 8 ! ..., . .._ L di 1-1/V, Current Schematic • sAkErt F Gt4tt FMC lifts34`MO. IP 1 .21 ._COL h.+:. 13 5zrss t.LQN TO T 1 ----LH -:---'. H . ,f 1 Eat .i _, _.__________,:Th„.., _ 1 I -_.._ , :J--ice_ °- i milkmen n D a 3.725"tg 10929' 4.112'PARKER MN NIPPLE 1 1 - 1 .:-.3.: H I I it %629* f+. ----- '..--- - ,* '`'.5- 1 —9.3, 1:41 . - . ..•V 1,4 C- -2 - II _ - -co, ,4",40,P, - ,r Win' I i ai ,, r L'*. .rn- ,1.,1* M 'A°1. r'4. Ar—f tau X Vi, "IP: T.c T r_ x aha" . 4 -c '`4 .. . ;..5!l - - . _ 1M 115'?' ( 'T-17--,--5-e. .. ,��-, -. • 1 - `+.+icilvvaE,,,,r MM - \. .,. ... .. .T - , ,.'fib V 363 41 C ._ —" 3 110. 11/ Post IA Cement Job ,0 ',k.,.L.:"Y Moll TVIIC,ImifiCR,Floic ePSA 4 34 v',... P1 -21 ," Cui RuNIII5,13-4,1 6 2r SHALLOW TO Tr*. ',..,4114 ROLL Rik.t.tX,RUN,5.01,113 IN fl* I . Liss, Jei•Vt.th'Y L ;RINI illi4N-•- i 1...„..,, I 1 I ISA,CCIE. E3 I - , ,if' r - _ i .40•121112121110. "1 . .44 .4 1 'I i 4,44,„4..4,4./.44444,44444.44.,4 4..44444,4,44.4..44444444441e,,- , PARKER SWN NPPLE !__ !Ain 10929 41.imum ID =3.725-@ - 2' 1 sex--TOC in IA 'II ..... - 1 0 . "..--1 10929. :-I • • ' ' . . - 4 -_ r ijoesr. . , '— ILLLAIII • , -- `--1 ., PCCIFKAVIA SL-MiOft, [ 108"k rX. OPOONLIDESS 0414MEA:, A.4.- r A--o-nlir1 .. --r,. • * = - , i' . , , - . . 4 --:.,'" --`Jr,- - - c3 1 ''MI 7;7 relreael 11101INAMA -- Lomwer _ . . . . • - , , crnoaT ha, *Mit , _ -----i' R • Imp- 1 , I ' *- ,ii- ,A•' 'Ar • "t 4 4 4 A I 4 4 , . 4 e • • w\� �j/�� THE STATE Alaska Oil and Gas ti +tom M ofLAS KA Conservation Commission t tt _� 333 West Seventh Avenue •4/14411011,7 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer 22011 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Pool, PTM P1-21 Permit to Drill Number: 193-059 Sundry Number: 316-264, 316-371, 316-375 Dear Mr. Hibbert: The AOGCC denies the enclosed applications for sundry approval relating to the above- referenced well. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. oerster Chair DATED this 5 ay of August, 2016. RBDMS L1.- AUG - 4 2016 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COM/16N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing VI Other PC Leak Cmt Sqz RI • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 193-059 ' 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ Service H• 6. API Number: 50-029-22363-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No WI PTM P1-21 9. Property Designation(Lease Number): 10. Field/Pools: ,q/!Y V n 9 2016 ADL 0034622 . PRUDHOE BAY,PT MCINTYRE OIL • 11. PRESENT WELL CONDITION SUMMARY A �°�►�° Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): u (IJaQj. 11525 9202 11432 9126 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"91.5#H-40 44-124 44-124 1490 470 Surface 3979 10-3/4"45.5#J-55 41-4020 41-3550 3580 P090 Intermediate Production 11477 7-5/8"29.7#NT-95HS 37-11514 37-9193 8180 5120 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 34-10954 Packers and SSSV Type: 5-1/2"T1W HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 10874, 8676 4-1/2"Camco TRCF-4A SSSV 2224, 2171 12.Attachments: Proposal Summary 0 Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0 Service R 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ❑ WINJ ❑ � IL- 16. �DSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG Il/'r I C GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Burton,Kaity be deviated from without prior written approval. Email Kaity.Burton@bp.com Printed Name Burton,// ttKaity Title Pad Engineer // Signature (:1 Phone +1 907 564 5554 Date CA- 2,01/o 1 I �(o (/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Integrity `� _ 2Ce,1{ Plug 9 ty ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No fig Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL RBDMS /, AUG - 42016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate O • N f6 m U) IC) N CO I- N d' CO N = LC) O I� M 1 LC) 00 LC) LC) Q CA CO LC) CO O CO I,- r-- c) a, O 't CO CO r N r- CO 0) a CO CO CO CO 07 o CA O O CO CO CO CO CO CO CO CA O) I- O. O V CO c to CO CO N N- V L LC) O) CO CO O CO CO 0 0 G r In N- tri N O7 V' O) 0 o r LO (` CA r N CT W 0 CO CO CO CO CO Cr) 0) 0) O > In CO CO CO 00 CO CO CO CO O) 0 I- LU 0 0 0 N Z LU W I- H OJ CL 1.110 0 0 < Y Y O N O N CO O r r p (n Cn J W U U W W V O) r M CO C)) LC) CO O J J J Q ¢ Cn CY y 0 0 r r r r C\J co < < < W d O Z 0_ 0_ Z 0_ J LLI 111 0 J 0 r r r r r r r r r Z 2 0 J J a z = = 0 0 [L H eL U O O W W W w CL Q Q V r- 2 2 2 0 cn cn u) cn cn CU N - I i-+ r a aa2 r N O N r O r r LC) p, CO U) O N IC) N CA N. P(100 L d O O r r r r r N 1-' p = = = = = r r r r r r r r r L a ami G ctc_nJ = 00wJd 2 2 O cn cn cn cn cn a n. a, O .2 U LL a s a s LL a s u- to' a QOWWQWWCL a < Q < a a <C a a 0 t d a 0 m 0 CD 6M) OM) d' 6M) CO O 0 0 O_ N N O CA O) CA O) N Z W Z r ` C Z (L' W W " M M CO CO to CO Wa 0_ 0 L.LLJ N LL O. 6) N L) in LOL j < 0 __II-- J -J CL CL 0 CO 0 D W J J Q O W W Q Q Cl CO LL 1.1 LL Cn CL d E <a Z r r r r r r r r r N N N N N N N N N LL Cl Cn O LL N (L' LL r r r = = = = = = J EL a a a a a a a a Q Q m m L cn a re • P1-21 PC Leak Cement Squeeze Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Kaity Burton (907) 564-5554 History P1-21 is a Not Operable produced water injector schedule to be converted to WAG service over the next few months. During an injector conversion screening, an MIT-IA failed w/ 0.6 bpm @ 1900 psi. P1-21 has a TIW HBPP packer which is known to be notorious for leaking. Also, a recent caliper run 1/23/2016 showed wall losses up to 37% at about 593' MD. Nonethelss an LDL run on 04/17/2016 showed a PC leak at 7654' MD and with no leaks in the tubing or the packer. The plan forward is to squeeze cement into the IA to fix the PC. The cement will be brought up -500' MD to cover the IA leak as well as the 37% wall loss in the tubing @ 593'. Objective This cement job is to repair a PC leak @ 7654' MD and regain operability of the well. Cement will be - circulated down CT and up the IA. The new cement top in the IA will be @ -500' MD. Procedural steps E-Line 1. Set bridge plug just above production packer. 2. Punch holes in tubing directly above bridge plug. 3. Set cement retainer above tubing holes. 4. FB -to verify circulation and retainer integrity. Coiled Tubing 5. Sting into cement retainer and pump cement into the IA to get the TOC in the IA up to -500' MD. Fullbore 6. MITIA to 2500 psi. Coiled Tubing 7. Mill out cement retainer and bridge plug. Slickline 8. Run SCMT from surface to verify cement top. DHD 9. Perform AOGCC witnessed MITIA to 2500 psi after injection stabilizes. • SAi-Err' r8O P 1 -2 1 CI3L*t.n,^405 13,93 6 2 SKA4.1.' ON 1'0 tr-* OPEN Hpa E If&OG RUt4 O.Se 93 P rf* USt - JalliklitrY LOG Of 7,,18: OH T 6,4 s*** , . - 0 „ - •iZ 108/6, 7.4* • I 2224 -J , - Minimum ID 3725 I 10929' 4-12" PARKER SWN NIPPLE J I I - 1 10912' H -27-- t 10929 H: r 1095r imomeimmiro 109 —-.%Af NTT:fog:A-TN 7' crc Dgirs.a. rs *SG -7.7P PiRr .17 a Rt.°4, t .tr-4 1-1 11 4-12' 't 44, „t‘ti r H 1151,3- 'Y93 ORG NAL 04A Pt.ET:OS —rt.% 0417. 7çr ** CY, -Tf-577-4 2 I STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMf N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well 0 . Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 ' Other PC Leak Cmt Sqz 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 193-059 • Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 3. 6. API Number: 50-029-22363-00-00 99519-6612 Stratigraphic 0 Service 0, 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PTM P1-21 RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0034622 • PRUDHOE BAY,PT MCINTYRE OIL • J U L 15 2016 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): JL OGCC 11525 • 9202 11432 9126 - Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#11-40 44-124 44-124 1490 470 Surface 3979 10-3/4"45.5#J-55 41 -4020 41 -3550 3580 2090 Intermediate Production 11477 7-5/8"29.7#NT-95H5 37-11514 37-9193 8180 5120 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 34-10954 Packers and SSSV Type: 5-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 10874, 8676 4-1/2"Camco TRCF-4A SSV 2224, 2171 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service I1 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Hibbert,Michael be deviated from without prior written approval. Email Michael.Hibbert@BP.com Printed Name Hibbert,Michael Title Well Interventions Engineer Signature ' N ' a� Phone +1 907 564 4351 Date 7/mil 6 Paa l I COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: -.-- k 4 - 3`7 k Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No Be Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. ree,./(,(6 Attnts in Duplicate ia , • • cuN to m in Lf) N CO N- N V CO N = to O L� CO C 10 00 L() Lf) p_ O (b Lf) ch O co N- N O) w O ' CO CO r (N N- CO (3) O 00 0o 00 00 C) C7) C) O O 00 co co co 00 co 00 6) O) o> H a 0 H CO C7) Ln CO CO N N- NI- .0 Lf) O) CO CO O CO CO 0 (0 Q. r U) N- Lf) N- N O C) 0 a) O r Lf) I� a) r N CA h W 0 00 00 00 OO OO CA O O O > O CO 00 CO CO 00 CO CO CO C3) 0 > w w 0 w O• 0 co z w w w 0 a U) <g Y U O > M N O N ct 00 O r r O RI O O U U W Ce W V C) r CO CO 4) U) CO O J J J Q Q Co W rt • O O _ N CO 'Cr 0 0 0 J W W -, Z O co z z zcp o o a o a E y = _ = z 0 H 0 U U U W d at Z Z W W W a H H Q _1 Q V r 2 2 2 0 (n U) 0) U) Cl) RS N — I Q %—. a- 0_ 12 a12 _ E N O N v' r O r r Lf) p0 a)_ c� Ln O N � N- O) N- N- O .fid . . . . . r r r r caa � L a) O 2 _a = J1HH0_0 co L O ((00 u) co co to C) CL y 0 U C LL LL. LL r Q' L.L. Q' (". LL "150- 0- 0- WWMWWM aQQQdd < M0- < 0 t a) a a) H D 0 NI- 0 0) 0) COMM 0 0 c 000) rnrn � 0) O) CD w Z O N N _ .- = _ r r N ZZ LL < w M M (�O C\O CO 0�0 N LL y N N A- r .- - D a Ow 0 0 w ft a 0) N L() Lf) N L) L!) I- Q 0 J H J J J w Cr a O m 0 D w J J Q O (uw < a co LI LI LL co a m a) E m z N N N N N N N CV N W a Co O J LL N Cr LL N r r r r r r r a a a M M a d Q- a mQ Q m m LOi LL cocoa_ w • p Well: P1-21 P1-21 PC Leak Cement Squeeze Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Kaity Burton (907) 564-5554 History P1-21 is a produced water injector that was scheduled to be converted to WAG/MI service over the next few months. During an injector conversion screening, an MIT-IA failed w/ 0.6 bpm @ 1900 psi. Also, a recent caliper run 1/23/2016 showed wall losses up to 37% at about 593' MD. An LDL run on 04/17/2016 showed a PC leak at 7654' MD and with no leaks in the tubing or the packer. The plan forward is to squeeze cement into the IA to fix the PC. The cement will be brought up -500' MD to cover the IA leak as well as the 37% wall loss in the tubing @ 593'. Current Status The well is currently classified as "Non Operable" by BP due to a production casing leak. The well is currently shut-in until the leak is repaired. Reserves Economics Estimates of remaining recoverable oil in the pattern based on offset waterflood only pattern would suggest that we can recover an additional 1 MMBO. This well is being progressed as one of the P1 injector conversions to MI capability. Volumetrics suggest conservatively another 1 MMBO oil recoverable if the conversion to MI capability is executed. A RWO is not being progressed as we have clear evidence of leak location and otherwise integrity of the well is good. The plan proposed is very economic and should restore the injector to operability for the anticipated remainder of waterflood field life. Objective This cement job is to repair a PC leak @ 7654' MD and regain operability of the well. Cement will be circulated down CT and up the IA. The new cement top in the IA will be @ -500' MD. An AA will be requested to allow this well to be a WAG/MI injector. Post-Job Evaluation This well will require an AA prior to injection with the following proposed evaluation criteria: ➢ MITIA and MITT ➢ SCMT to confirm Top of Cement (TOC) ➢ Temperature Warmback Log & Water Flow Log to verify no flow behind pipe LongTerm Integrity Monitoring ➢ Daily pressure-monitoring of the 500' deep Inner annulus ➢ 2-year (biennial) MITTs and MITIAs ikurrent Schematic 4110 STYMM racHWR,FMC SPSH g 34"yu CS1 RUN oil 3413 IS 21 STALL ON TO 1t OPEN MIME REF LOG RUN OS OSS3 t NE TOT tft .,,.. USE JaNELRY LOG Of 7!1.113 FOR TIETt4**4 1 I a., ----1 2224" H. - -,...'4- --!'r :' ' :-: 1 V , " T.47 '0". .', '',0' , z•'• 7 .., 44'• hi 4027 _A 0 • 4e.-L., .1---„c .:.,: 4 --.7 4 kac,'a a*, . # t i0816" 4 ' ..:...c3,‘7 TR 7,...'in•47. 0 3 r IMinimum ID =3.725-@ 10929 4-1/2"PARKER SWN NIPPLE 1 '.. ,.,: _......1 108 74ft c 0 •.:. '0'''%.%4.70','•37,'. - - ''7 „1 10912* H4 " .,'C4A.P.r.r,i-,or,k4..,n •:,7; -i:", 1 1 1 10929, f.t . ,,,..,,,,,,-- : ,-2,,,- 1 1*...r. H icesx T--- k- 1085( • •7.,7F47.)*""Co.l's;,%AMA RN' AT.00. OPCPALITTENS ON05,06.1) AS104.1"AT 77)P 01117r 37 0 1"'"fa "4.;. i7t4e,t.....0,-,,..i.i-ktc.1 le T.,Not..t.'t.::0;vr7ir 144 0 ONO TACT ...".' ''**2 0 0205.14 S 'a.!4 ".34 0 0.Sit 3.33 P'.$ 0 05/11.A.St 0 020054.9'4 t 'T251 0 05/73037 *1 0 _I i maw 11432' 1 rYx*:kto H iisix I- 0GLcPttnos a. D' ..'.' a ar cr—o.,;,:, TRA7 NC, .1930.5,C ' ,•,,, ...,' 7..:,.., P4:r et..rx.00#*ion i Mask,1 2 OPost IA Cement Job • '5N-ETY NOM TIIGHNGli f-NIC WSH 4 34 MO . P 1 2 1 - (t&RUN 051313 IS 2r Su TO T HIE - OP#14 Kt E REI-LOG KM 05105,043 1.3 13-0 411 100" , " 3 314 f*,, -- - I 1 4 , 500-TOC in IA t,4- .' 4 ,C 0 24 H _ 10816' Minimum ID =3.725-@ 10929 1 4-112"PARKER SWN NIPPLE bI is. 1.1.74' t---- 10912` H4. •2-N.c....s."7, ..' 1 tc929- f+, '':,,,A....rP:,....".4,-, : '-:',.. - I -1 *•v. If C 1 4(1"' 't-L 10)53, I "Myr —- PrITO ROOM SUMallart •-", Rat,Xx 'ir'41VOCNIS ON05‘.35.93 A*it; 7 A-770P of3Zr -3-7 4*-ir.' LI X 4 i ii44 d 4 „i7.' J=S a A - ir' - *"3 32 •5)4.:. J :40 104 * 40- *. 'Vie 33090 0 04234 *302 31 312 0 0209043 1 IA- 7 '5324 I"33,4 0 Oir 1793 ' 4tr - •31-53 "M8 0 OV13.193. 5'90 31 390 0 02095,4 1 VS' 75 —01 '1,zo. 3 0503 3,13 : •10- , * 274 33*I 3 0S0 3,13.31. 1 4,0" " •5-303. 1-140C 3 07-4 r**, - 41 NM 11432' 1--1 N., N '41%tct\%% %k ovo,mt,t '-.".:"' :* ' S'- '' C -3'-'.... H 1151y ----1 ;003T MOWN RC L Nir ORO 0441 C04,3 Pt_CV ON ' :.- *' Pt,*,-, -5--_.5r-3 3:-.4 WM,: m 2' -- "rg, .„„. 4003.4 `o” ''' ..*:\R-4r C.'44":"rs1 2.14:46 r' 7 4 7 7 I 7}7 711"—^ir pp c".„arit,o,-,:okavi,4 * 3 Job Notes • LLR for IA(PC leak) is -0.6 bpm at 1900 psi. • BHCT is estimated to be 135 F. • BHST 142 deg F. Cement Calculations Cement Job Total cement to pump 272 bbls Key Parameters Cement Type/weight: Unislurry Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80°and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 7 hours 1 Cement thickening time:Mix on the fly Activity Time(hours) Shearing time,quality control,PJSM 0 Cement displacement 4 Cement contamination 1 Safety 2 Minimum required thickening time: 7 Cement Ramp for Blend (1st cement job) Time Temp Pressure 0:00 90 0 1:00 100 2800 2:00 120 2000 7:00 60 400 Volumes: top Punch volume MD MD Size ID bbls/ft. Ft. bbls 4-1/2"tbg 0 10850 4-1/2" 12.6# 3.958" 0.0152 10800 165 7-5/8"29.7#x 7-5/8"x 4-1/2"annulus 0 10850 4-1/2" 12.6# 6.875" 0.0262 10800 285 4 i • % i' .^''`i r//,' ,y i:.. n ,tib /,.,,,.,,,,/...... ,r ,lu:, ,,:xi„,�.,r;ii////„/JJJJJ,..,,�,:/iii,'.:,x,:/^r”rr,�fi>,.�/r��rr�/�-l�`.;"���r ���/���%�/,.�%''`/fi�F ifir.4.,u�!i'F;,,�„/.✓�.�,/�J����,fir«f�f,,�,s.r--"v .. 1. Set 4-1/2" composite bridge plug in the tubing @ -10,847' MD (middle of the first full joint of pipe above packer). Reference attached tubing tally dated 5/9/93. 2. CMIT/LLR TxIA to 1900 psi to verify CBP set. The CMIT should fail due to the PC leak but the LLR should not be significantly more than -0.6 bpm/1900 psi. If the LLR is significantly higher than this then call Interventions Engineer for plan forward. 3. Punch tubing w/ 5' tubing puncher across collar @ 10,825'-10,830'. Note indication of tubing punch in AWGRS (if evident). If no indication of tbg x IA communication is evident then pump to verify circulation down tubing and up IA. 4. Set 4-1/2" Halliburton SVB squeeze packer (composite, sliding-sleeve-style cement retainer) @ -10,822' MD (middle of 10' pup joint). MIT-T to 2500 psi to verify retainer set. 1. Rig up a micromotion to IA returns. This will help determine if the PC leak is drinking any cement and track the cement top in the IA. PT CT connector & CT to -4800 psi in anticipation of high circulating pressures towards the end of the cement job. Note: usually pressures do not get higher than 4000 psi during IA cement jobs, but this job will be attempting to bring the cement top higher in the IA than has been attempted before and circ pressures are likely to be high near the end of the job. 2. MU Halliburton SVB Squeeze Packer cement retainer stinger. RIH and circulate heated (160F) diesel to the stinger taking returns from the CT x TBG backside. From just above the retainer, circulate -130 bbls of heated (160F) diesel out of the CT to displace the CT x TBG backside to diesel for the cement job. 3. Sting into cement retainer. 5 • . 4. Establish diesel circulation down CT and up IA to tanks. Verify coil backside is SI. Pump the following fluid schedule. Note: Do not pump any freezable fluids (other than FW spacer and cement) through retainer into the IA as these fluids will remain in the IA after the cement job and may end up across the permafrost, freeze, and collapse the production tubing. a. *285 bbls of heated diesel (160F) b. Minimal FW spacer-divert this upstream of the CT so that nothing but diesel or cement goes into the IA. c. 272 bbls cement per design d. CT volume of FW (unsting from retainer w/ last 1-2 bbls of cement in CT) 5. This should put the TOC in the IA @ -500' MD if there are no lost returns. It is expected that the PC leak will drink little cement due to the small size of the leak. Keep track of returns from the IA to track the TOC in the IA. In order to keep a rate of-1 bpm be prepared for CT pressures to be over 4000 psi towards the end of the cement job (when water is displacing cement out the CT). See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. 6. Unsting from cement retainer w/ 1-2 bbl of cement still in the CT and lay remainder of cement in 1:1 on top of cement retainer. Monitor CT x TBG pressure closely as the stinger is pulled out. If the retainer fails to seal, the CT x TBG backside pressure should jump to -3800 psi. If this occurs, hold CT x TBG backside pressure (3800 psi) throughout the rest of the job. This will keep the cement in place in the IA despite a failed cement retainer. SI IA for the remainder of the job. This will leave all of the cement that was laid on top of the retainer to mill later, but will preserve the IA cement job. 7. If the retainer holds pressure then contaminate cement and circulate out or reverse out cement down to the retainer. 8. FP tubing down to 2500' MD as needed. ,,,,r ..r ;e, :- ;,''i;i�: g 'a,«t=7�l i i r /z,R:r'f�%'r//Iffy//y'elorf//A f%,r�"/,1�' /' �,�rr/r,,,r-`�r/�>tiF .1 �,if,.r`j;;r r%',//,•`'rrr�. r , / ,/ 'z rl /r j "`a%/r' ,.ko s%!"A '/rr �,,��, .. _ :,,.. ,,,,.r,,,r.. /, �r,.,f rr, .// Fr.,or�%r�!..'ifF,ffif`'��/r.' Contingency#1: If at some point cement locks up and cannot be pumped into the IA due to high circ pressures then cut cement at surface, close in IA, and unsting from cement retainer. If retainer appears to be holding then reverse out cement if possible or lay in cement 1:1. If necessary to lay in cement then contaminate and circ out cement to surface. FP down to 2500' MD prior to rigging down. 1. MIT-IA to 2500 psi. Establish LLR if fails. fff F/! ri 8 r rfy,c/fif rJo . % , 6 O ! Coit 1. MU 3.70"junk mill. RIH and tag top of retainer (expected 10,770' MD). 2. Mill through cement, retainer, cement and the CBP. Push CBP out of tubing tail amd POOH. ':::71;55;1:;;;;;11:://4 IFS/ ,ill +' r .. //y,,.�r� Ji/,%: x ,rr r,rG�/Si,< ..Lii,,: ✓..,s6.>f,/%x,,:E�it, n r�r/'�fr r� ,i 1. Set TTP. 2. MIT-T to 2500 psi. 3. Run SCMT log from tubing tail to surface to find TOC and relative bond. 4. Pull TTP. 1. WFL and temperature warmback log to indicate any flow behind pipe. ,,,rrl�''s,',j I„r"'" 2. After well is on injection and stabilized, perform AOGCC witnessed MITIA to 2500 psi. ! ,/ `1:Y'; r// /f y � r,�,� i �/J fr%✓ 7#.'.��� �/•��1� 'F,�„ei9x a=;=� r/�.. �.�/ ", r :r%r:s'`rf/ j f,�/, r'/,.,�,f1///fit fri'',r�i�ri�'��,/�,!`f://.,rjff%JjJ"1f,'r%,%��'�,/j',;if,//���'J/� l r`fl,..;�f`G//i r i, ;,yrr'6rt; �rIl'�"�i,,/,lF""""'/'','/�'`/4/7,%d/,'%'f fl 1. Add Biennial MITTs and MITIAs to AnnComm for additional monitoring of the well integrity. 7 • • • . Tutu Ct - 33919441:1Y T~� ''� POOL 7 Da Is 33093 1 -BP P1-21 I 4.5 1-60 1136 Air,, t 2. OA' 1101Tb1.10 SF 111a4 61 1 OD LENGTH MOP 0•OiTOM 414-WI.EG, NSCT BOX 400 5,30 .91 1095202 10953 8.3 X,[)PUP N:SCTPINrTpSBpX 3 96 5.56. 2.40 10950.22 10952.82 PUP JT,4-1:7 705 BAP 3 96 5.58 9,87 10940.35 10950.22 PUP Jr.4.1.7 TD,S 1381' 3 96 5,56 9.95 19939,40 10949 35 Parks 4 5'SWN P pp4.,w. RHC PLUG 3 73 5.231 1.50 10'928.90 10930 40 PUP JT,4 17.7DS BAP 3 96 5 56; 5.90 10923 00 1092890 PUP JT,4-1,7°IDS BMP 3,98 5.58 9.93 10413.17 10023.00 Par10(4-1.1-$W$n11PPLE.TPS i 3 51 5,27 1.37 10i/11.04 10813,17 PUP JT 4-1 TOS E38P 3.96 5.56 9-19 10'901 g7 1091 t 80 PUP.121,412•TD5 EMP 196 5.56 9.,90 10891.49 10901 87 PUP Jr.4182'J'OS 36P 3.96 5.54 5.96 10985.99 10491.59 OUP?,4.1)7 T06 PIN a 5,12•NSCG BOK 3.93 6.25 .90 10885.09 10865 99 TTWNLLOIJTEX7EN$10N 4.00 5,53 5-77 10879.32 10885.09 1114 7.549-0181iP Par KEA 4,00 6 58 5.03 10474.27 10879 32 1 TIW LATGHASSEMB.Y 4.00, 632 1,25 10073.02 101974 27 1 PUP JT.4-17 TOS S&P - 3.96 5 56 1.05 10866 0'7 10473 02 1 1 JT 4 12'TWANG .1 3.96 5.56 39.75 10627 19 10866.97: PUP Jr,4-1/7 TCS 88P 3.96 5.SC 9.9S 10817 36 10827 10 PARKER 4.17 SWS NIPPLE. TLS 3.61 5.23 1.37 10415 99 10917,34 PUP J1',4-1/1"TIM S&P 3,99 5,54 9.91 10606.04 10615.99' PUP JT,410•T1,)S BAP 3.96 5.56 9.74 10794.34 - 10808.04 I JT 4-lir TU68,3 82 3.96 5.54 39,74 10756 63 10796.34 PtJP 47.4-111'•706 MP 3.96 5.56' 9.15 10748.88 10756.83' X37, BTC 8ox X TCS Pin 3.96 5.54, 1.91 10744.77 10746.6.81 4.•12'PAERLA TMPDX 004 w Dummy 3.83 7 03' 7-31 10737 48 10744 771 X-0 TD5 Box X BTC Pr 3,94 5 56`= 1.99 10735 47 10737.46 PUP JT.4-112'TOS 04P 3 96 5.56` 9-60 10725.57 10735,471 147 ITS 4-112•T1J9144 43,8149 3 96 5.56 5934.06 4891 49 10725.5'7; PUP JT 412•TOG ::P 3 96 5,56 9.86 4681 63 4891 499 X-0, BTC Bow X MS Pin 3 96 5 56 1.91 4679 72' 419191.83 4.17 1ERLA TMPDX GLM,w,Dummy 3 83 7 03 7,32 4672 43; 41979.72 XD, MS Box X BTC Pin 3.96 5.56 1.19 1 4570 41 4872.40 PUP JT,4-12'T4$Bap 3.96 5,55' 9,67 4 4060.54 4574,41 64 JTS 4.117 TUBING 8150-4215 3 96, 5,56 2013.91 2246 63' 4660.54 PUP JT,4.17 TPS 86P 3 36 5.56: 5.96 2240.85 2246.63 FLOW COUPLING 41+2'TDDSpr,x FOX tot 1 9.01 2230 80 2240.68 CM100 TRCF4A•35311°PDX 8418 3 01 6.30 6.67 2224 13. 2230.90 FLOW(=PLNG 4-112'TQSpr,x FOX box 9.31 2214 75 22124.13 PUP JT,4-192'JOS UP 3.96 5 56' 6,90 2208 0S` 2214.75 55 JTS 4.111'TUBING 8216-4270 3 96 5 S6 2172.53 38 3? 2205 85 ?' r: "` �1"jl •well' 3 19,86 34 10 POOL 7 Rai Tta.'la T., .r LDS 36.. 34.01)' MEIN -.-4_......-______, 2T0 }be 4-1r2" 12.44, 990, R3.7O$ Tubing 2 Gas Lit Msxldrats Up wslg11t Of Iubtng 4tring . 190,004/ IM Doom W.15h1 o1 40In.0 , 155,0001 Stainless Stool Contra lino.bands . 58 ► 1 Los PBTD s 11432' f 8 STATE OF ALASKA *ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well H , Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing H • Other PC Leak Cmt Sqz m 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 193-059 • Exploratory 0 Development ❑ 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-22363-00-00 ' 99519-6612 Stratigraphic ❑ Service IZI, 7. If perforating: 8. Well Name and Numb RECEIED What Regulation or Conservation Order governs well spacing in this pool? s Will planned perforations require a spacing exception? Yes 0 No I3 PTM P1-21 • I I Y 9. Property Designation(Lease Number): 10. Field/Pools: JUL- 2 1 2016 ADL 0034622 l PRUDHOE BAY,PT MCINTYRE OIL • 11. PRESENT WELL CONDITION SUMMARY AOGCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD):AOGCC 11525 • 9202 • 11432 9126 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 44-124 44-124 1490 470 Surface 3979 10-3/4"45.5#J-55 41 -4020 41 -3550 3580 2090 Intermediate Production 11477 7-5/8"29.7#NT-95HS 37-11514 37-9193 8180 5120 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 34-10954 Packers and SSSV Type: 5-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 10874, 8676 4-1/2"Camco TRCF-4A SSV 2224, 2171 12.Attachments: Proposal Summary 0 Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service H 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ B • WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Hibbert,Michael be deviated from without prior written approval. Email Michael.Hibbert@BP.com Printed Name Hibbert,Michaelej Ajaer ,N01'U Title Well Interventions Engineer SignaturePhone +1 907 564 4351 Date 9/ /�g.etJ,g- ti. 79.. .<-/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: \Le _ 375 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No ❑� / Spacing Exception Required? Yes 0 No Bd Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL ,, ?0-r/ Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • C) N m• In Ln N CO 1- N V CO N t In O f— M N- LU CO Ln In G O) a0 LU M O a0 N- N- 6) C> O .Tr CO 00 r (NN- CO 6) p a0 a0 a0 aO 6) 6) 6) O O aO a0 a0 a0 aO a0 oD a) 6) > H a O V CO O) C!) CO CO N N V LO O) CO CO O M CO O O o- r LO N- LU N N O 4 CA 0 • O .— Ln N- O) r (Nj O) N W 0 CO CO CO CO CO O) 6) 67 O > p co co co co co co co co 6) 0 > 2 H w � o 00 Z UJ w p W0 H H J Cl W O g g Y 0 0 o' 0 0 W Y Y H g cC N O N a0 O r O CJ U w w ' V 6) M C9 6) LU CO O J J J Q Q (n z ¢ ¢ Qwa aOZO ��11�� = = = = = r r 0 0 0 J W W W Z Z Z n n J J a a Q = a a a , a O O O Wz = iZ p Z w w w [1 H H < J < C. r 2 2 2 O co CI) CO Cl) cn N Qa a � . N O N r O r r In Q M LU O N Ln N- d1 N- N- O ) O O r r r r N• M cS a s- 0 C> Y O - J = 1- O a J d 2 2 O co co cn co co a, d y O .2 0 • LL LL a_ a LL LL is CL W W W W CL W W N Q Q Q cL d Q d cL Q D. 0 a) C> a y F- 115 -1 0 0 0 OM) 6M) 6M) OM) O 0 0 O o o O rn rn 0 6) O) O w z O NN — � � � v- N Z Q LU c cO CO CO CO 00 0 W 0 U p N w CD CN N om ; ; Z a J W W w W O O) O Ln M) In Ln N- CO O p W J J p (Y Ll Q Q a co co a cc C) E Z• r r r r r r r r r N N N N N N N N N w a co 0 w N w � a = = = = = O a a CO a a a.m w Jw a Q ¢ m m w � coccocn acC • • *64 Well: P1 -21 P1-21 PC Leak Cement Squeeze Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Kaity Burton (907) 564-5554 History P1-21 is a produced water injector that was scheduled to be converted to WAG/MI service over the next few months. During an injector conversion screening, an MIT-IA failed w/ 0.6 bpm @ 1900 psi. Also, a recent caliper run 1/23/2016 showed wall losses up to 37% at about 593' MD. An LDL run on 04/17/2016 showed a PC leak at 7654' MD and with no leaks in the tubing or the packer. The plan forward is to squeeze cement into the IA to fix the PC. The cement will be brought up -500' MD to cover the IA leak as well as the 37% wall loss in the tubing @ 593'. Current Status The well is currently classified as "Non Operable" by BP due to a production casing leak. The well is currently shut-in until the leak is repaired. Reserves Economics Estimates of remaining recoverable oil in the pattern based on offset waterflood only pattern would suggest that we can recover an additional 1 MMBO. This well is being progressed as one of the P1 injector conversions to MI capability. Volumetrics suggest conservatively another 1 MMBO oil recoverable if the conversion to MI capability is executed. A RWO is not being progressed as we have clear evidence of leak location and otherwise integrity of the well is good. The proposed plan is economic and should restore the injector to operability for the anticipated remainder of waterflood field life. Objective This cement job is to repair a PC leak @ 7654' MD and regain operability of the well. Cement will be circulated down CT and up the IA. The new cement top in the IA will be @ —500' MD. Post-Job Evaluation This well is an injector so an AA will be applied for to allow for WAG/MI with the following proposed evaluation criteria: ➢ MITIA and MITT to maximum anticipated injection pressure ➢ SCMT to confirm Top of Cement (TOC) ➢ Temperature Warmback Log & Water Flow Log to verify no flow behind pipe Long-Term Integrity Monitoring ➢ Record WHPs and Injection rate daily (includes pressure-monitoring of the 500' deep Inner annulus). ➢ BPXA will submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report. ➢ 2-year (biennial) MITTs and MITIAs to maximum anticipated injection pressure. ➢ Maintain IA pressure below 2000 psi normal operating limit. ➢ The well will be immediately shut-in and the AOGCC notified if there is any change in the well's mechanical condition. ➢ After the well is shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 2 i • bp DRAFT AA BP Exploration (Alaska) Inc. requests approval to continue WAG injection service with an IA cemented to —500' MD into well P1-21 (PTD # 1930590). Well P1-21 currently has a production casing (PC) leak at 7652' MD which will be repaired, per attached Sundry, by cementing the IA and bringing estimated top of cement (TOC) to —500'. An initial cement evaluation log (SCMT) will be run to verify cement placement after the initial IA squeeze as well as a temperature warm back and water flow log (WFL) obtained to verify no flow behind pipe. An MIT-IA and MIT-T will be conducted to 2500 psi to confirm the success of the repair and that both the tubing and production casing are competent. If continued operation of the well is granted, the inner annulus operating pressure shall be maintained below the MOASP of 2000 psi. In summary, BPXA believes Prudhoe Bay well P1-21 will be safe to operate pending the successful completion of the planned work and testing outlined in the attached Sundry, and requests administrative approval for continued WAG injection service with an IA cemented to —500' MD. If you have any questions, please call me at 564-4303 or Jack Lau/Adrienne McVey at 659-5102. Sincerely, Attachments Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Doug Cismoski Lau/McVey GPMA Operations Team Leader Katherine Burton Ryan Daniel • • Prudhoe Bay Well P1-21 Technical Justification for Administrative Approval Request July 19, 2016 Well History and Status Greater Point McIntyre injection well P1-21 (PTD # 1930590) has a PC leak at 7652' MD which prevents current injection service. This well is being progressed as one of the P1 injector conversion to MI capability wella. Estimates of remaining recoverable oil based on offset water injection service only suggest 1 million barrels of oil (MMBO), with another 1 MMBO oil recovery if the conversion to WAG is successfully executed. Cementing the IA as an economic integrity repair option, as proposed in the attached sundry, would restore injection service for the anticipated remainder of service life. A SCMT will verify cement placement after the initial IA squeeze. A temperature warm back and WFL will be obtained to verify no flow behind pipe. Lastly, a MIT-IA and MIT-T to 2500 psi will be performed to confirm the success of repair and that both the tubing and production casing are competent. Recent Well Events: > 06/03/14: AOGCC MIT-IA Passed to 2500 psi > 01/20/16: PPPOT-T/IC Both Passed > 02/19/16: MIT-IA Failed w/ LLR of 0.6 bpm @ 1900 psi > 04/18/16: PC leak found @ 7652' ELMD Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A SCMT will verify cement placement after the initial IA squeeze. A temperature warm back and WFL will be obtained to verify no flow behind pipe. A pressure test of the tubing and production casing will be performed to 2500 psi pending successful sundry repairs, demonstrating competent primary and secondary barrier systems. Pressure on the inner annulus is maintained below the normal operating limit of 2000 psi when the well is on-line. Proposed Operating and Monitoring Plan 1. Allow water and gas (WAG) injection service. 2. Record wellhead pressures and injection rate daily. 3. Submit a monthly report of well pressures and injection rates to the AOGCC. 4. Perform a 2-year MIT-IA and MIT-T to maximum injection pressure. 5. The well will be shut-in and the AOGCC notified if there is any change in the well's mechanical condition. . 4iCurrent Schematic SAFETY NOTI 18O Ort,FMO ifioSil g 34'MO — RUN 051393 IS 2 T SHALLOW TO THE A.,ka ye. 13 I -2'I a*.OPEN HCLEHEF LOG RIM OStOSI93 N THE Flitu USE JetMELRY LOC OF 7'1843 FOR I 8E.-18i*** .V 2224. H, , :-. WA' 0 4 7ts,1' .7. 4 A14 A SA44 4027 , — I 1 1 10816. Minimum ID =3.725.*@ 14929. 4-1/2"PARKER SWN NIPPLE .< *.,., 1 10874* 11- s, .7 I I 1 10912 1-14 • .2-74..z‘,..:7,,'s or,'t3:..' :7 ' '''- I III 109 29" H,.. , :-.,7,-,.z.......,,,,,,,,, : 7 --,,....F7 I TX,. '2 i,t .. X. .-'41,*1.V.'.:4.4 C ) SA" Fi 10953" I 109s( - :::„ ••••,:- et.zr.-.:, •:,. L. '..'.'•'' 10950 - Prqroqxrce.1"....L.NAktik.Ps, ;ET„,,-.).S • ",,crill.,,T,C0,41:.re.7..,:,..c.7",c 7 sr SZE :,3" N717.17'.`A. :to--: 444 3 W.* ' '"•7:: "*'33' 3, '.:4," I 11432. I ;$14.049:41.4.34.1/410 I -.'.'.- -,,,-, :•.'4-t• \-: "..f. r .",r- H 115 13* I rONT MCPCP,qr Lvr 08'1 On 3 °RIG NAL COM PL Eros ..7-:.' ...7'..' 7..... .. : 'Ir 70% - '-..--," -04T1 Te '2...-' ','" - -07 Pr-""it‘ T :Nr.*4_ '•,,.f..c.4." -r - - - - --cp,.., -, •P*.t.7 'L .4 7: ra : 4. rrrtc- ' .._ :,.,‘,r:77, ''',747 BP et porat on,Airsirs! , • 3 ost IA Cement Job • r13- SAFETY t'Oft 113G H NCR EMC BPSH g 34M0 :r fT -v. P1 -21 -CBI RUN 05,13/93 27 SHALLCW TOT** A* OPEN HOLE REF LOGIAM 05/05i93 Ai THE ROLE& . r USE JEWELRY L(X;OF 7 1303 FOR TETN.-. *, r 500-TOC in IA 24. H Lre •zi; C) 402T IIP UMW * -YkAz.ra7 Minkritnn 03 =3.725**@ 10929.* 4-1/2. PARKER SWN NIPPLE >< 10874* ft .-y*—6"E -6,S. I I I j 10917 10929' H— 4 2 0'7, r..64 0 3 956" H 1095T I ` 10954 — **:- 11111111111111111111111111111111 10959 — 6* • PCRR)RA"C*N SLMMAR'- RIT -XIRNIL1X6% ' 66 ANGLEAT r3PPErr r a ‘t z .1 1.114 IT' 3 IA' 6 * **146I 3 23 - 3W 6 ' ""'2 0 02125A4 1A6 4 ' 2A 113t 0 0511 3.193 " 06 "15 I 68 0 05 I 193 6 "'40 0 0205,4 3 IA' 4 * 31. 0 25/1193 3 106 4 *41 " t0 O131 - " 375. vo 3OP1 AG 3 716 7 :1: 1 t' ' r H k_1111 06111093 ORIGINAL COM Pi ETI ON ' ' 6t.r"). 7'7 7 777." 7.7)e`r Z Fe• .... W--'-4 4 1 ",7 4:r I'vVII"\.*,• r{%.7. or.pr 4 " r") 161. OP 60orat >n A94444/ 4 • • .,‘" I SAt ETV NOTE 'MG FiNtat FMC SPSH g 34*MD - CO-RUN 051193 tS 22*SRALLON TO THE • — . t) P1-21 Proposed P&A EN FitZLE REF LOG Rt1.4 050543 Pi NE RIT LAE :1:1.4 • $.$1 Cement Plug#3 Circulated down ••Jr. • • . iit4Rigifili tubing,through tubing punches @ Att.A 44,- f I Vtlifigi [111 I —500' MD and up IA to surface Altir ..±..tot.4.4.4.44 '01 Cement Plug#2 Circulated down 14- 31""„Z 455. ' 315°3 4020 A tubing,through perforations @—1800' Emil MD and up OA to surface EMI.11.. - 1 I I 10816° 7=0 4.7=TR ‘,07. Minimum ID =3.725 @10929 4-112"PARKER SWN NIPPLE 1091 0 e 27 94 rmi. Cement Plug#1 Pumped FB or laid in — • with CT ?-2-rw., 0-3.*Vt-if t H SOSSY 10954" 01-7; 109 59. — Cc •.* PEPEORA-EA,.0,44461,74% r:420.4a,"XSZ 0.N ANG,E AT TOP PERE 77 0*1/ . *4 11* 10' 6 14-0, 3 3A/2 3 EA 3 IP- 8 ' " "2 0 0213314 3 11- 4 * , * 0 09.1 349 3 310" 4 * '51 0 & t31 13P 8 '' ' 11-3 0 020114 311" 4 "" 9/ 251 0 0501,3 3 IP" 4 —271 '*)8! 0 os,3,I 3 .141- 8 '"175 11403 0 07/7001 7'7 11432' ,kocrk.Y1‘,4 kItt‘tiotat I - `e r 11513° IX "4.37 *3-r4 AEC3,—"*" -#1.-7 /7, rA4401,- 0511013 ORIGINAL COM ET1ON ' ° rE-4 -AD% "7 -74 47 PS. 1/4 `lit * * ,44 -c 7'7 c 4 RA 4= -1-4**1 44=Ri :•, ° ' 's4, = r.; ,S ,:. /. :3" ei› piorst kask.ii 5 • • Wel P1-n Job Notes • LLR for IA (PC leak) is -0.6 bpm at 1900 psi. • BHCT is estimated to be 135 F. • BHST 142 deg F. Cement Calculations Cement Job Total cement to pump 272 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 7 hours 6 • • , Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 4 Cement contamination 1 Safety 2 Minimum required thickening time: 7 Cement Ramp for Blend (1St cement job) Time Temp Pressure 0:00 90 0 1:00 100 2800 2:00 120 2000 7:00 60 400 Volumes: top Punch volume MD MD Size ID bbls/ft. Ft. bbls 4-1/2"tbg 0 10850 4-1/2" 12.6# 3.958" 0.0152 10800 165 7-5/8"29.7#x 7-5/8"x 4-1/2" annulus 0 10850 4-1/2" 12.6# 6.875" 0.0262 10800 285 1. Set 4-1/2" composite bridge plug in the tubing @ -10,847' MD (middle of the first full joint of pipe above packer). Reference attached tubing tally dated 5/9/93. 2. CMIT/LLR TxIA to 1900 psi to verify CBP set. The CMIT should fail due to the PC leak but the LLR should not be significantly more than -0.6 bpm/1900 psi. If the LLR is significantly higher than this then call Interventions Engineer for plan forward. 3. Punch tubing w/ 5' tubing puncher across collar @ 10,825'-10,830'. Note indication of tubing punch in AWGRS (if evident). If no indication of tbg x IA communication is evident then pump to verify circulation down tubing and up IA. 4. Set 4-1/2" Halliburton SVB squeeze packer (composite, sliding-sleeve-style cement retainer) @ -10,822' MD (middle of 10' pup joint). MIT-T to 2500 psi to verify retainer set. 7 Coll 1. Rig up a micromotion to IA returns. This will help determine if the PC leak is drinking any cement and track the cement top in the IA. PT CT connector & CT to —4800 psi in anticipation of high circulating pressures towards the end of the cement job. Note: usually pressures do not get higher than 4000 psi during IA cement jobs, but this job will be attempting to bring the cement top higher in the IA than has been attempted before and circ pressures are likely to be high near the end of the job. 2. MU Halliburton SVB Squeeze Packer cement retainer stinger. RIH and circulate heated (160F) diesel to the stinger taking returns from the CT x TBG backside. From just above the retainer, circulate—130 bbls of heated (160F) diesel out of the CT to displace the CT x TBG backside to diesel for the cement job. 3. Sting into cement retainer. 4. Establish diesel circulation down CT and up IA to tanks. Verify coil backside is SI. Pump the following fluid schedule. Note: Do not pump any freezable fluids (other than FW spacer and cement) through retainer into the IA as these fluids will remain in the IA after the cement job and may end up across the permafrost, freeze, and collapse the production tubing. a. *285 bbls of heated diesel (160F) b. Minimal FW spacer—divert this upstream of the CT so that nothing but diesel or cement goes into the IA. c. 272 bbls cement per design d. CT volume of FW (unsting from retainer w/ last 1-2 bbls of cement in CT) 5. This should put the TOC in the IA @ —500' MD if there are no lost returns. It is expected that the PC leak will drink little cement due to the small size of the leak. Keep track of returns from the IA to track the TOC in the IA. In order to keep a rate of—1 bpm be prepared for CT pressures to be over 4000 psi towards the end of the cement job (when water is displacing cement out the CT). See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. 6. Unsting from cement retainer w/ 1-2 bbl of cement still in the CT and lay remainder of cement in 1:1 on top of cement retainer. Monitor CT x TBG pressure closely as the stinger is pulled out. If the retainer fails to seal, the CT x TBG backside pressure should jump to—3800 psi. If this occurs, hold CT x TBG backside pressure (3800 psi) throughout the rest of the job. This will keep the cement in place in the IA despite a failed cement retainer. SI IA for the remainder of the job. This will leave all of the cement that was laid on top of the retainer to mill later, but will preserve the IA cement job. 7. If the retainer holds pressure then contaminate cement and circulate out or reverse out cement down to the retainer. 8. FP tubing down to 2500' MD as needed. 8 •. Coil Contingency Procure • Contingency #1: If at some point cement locks up and cannot be pumped into the IA due to high circ pressures then cut cement at surface, close in IA, and unsting from cement retainer. If retainer appears to be holding then reverse out cement if possible or lay in cement 1:1. If necessary to lay in cement then contaminate and circ out cement to surface. FP down to 2500' MD prior to rigging down. Fullbore—Wait On Cement At Least 5 Days 1. MIT-IA to 2500 psi. Establish LLR if fails. '/, l ' 1. MU 3.70"junk mill. RIH and tag top of retainer (expected 10,770' MD). 2. Mill through cement, retainer, cement and the CBP. Push CBP out of tubing tail amd POOH. Slickline 1. Set TTP. 2. MIT-T to 2500 psi. 3. Run SCMT log from tubing tail to surface to find TOC and relative bond. 4. Pull TTP. E-Line 1. WFL and temperature warmback log to indicate any flow behind pipe. 2. After well is on injection and stabilized, perform AOGCC witnessed MITIA to 2500 psi. Weilintegrity Eraheer 1. Add Biennial MITTs and MITIAs to AnnComm for additional monitoring of the well integrity. 9 • 0 • SUMMARY f2pas..,. POO r Dote sr�rI3 4.5 1.-a0 TDB 12.5 40.5' ROLTbLto BF REAM 3) 00 LENGTH TOP BOTTOM 4117'WLEG, NSC1 BOX 400 5,30 .98 .10952 82 10953 80 X,© PUP NSCT PIN x TDS BOX 3 96 5.56 2,60 10950 22 10952 82 PUP J7.4-12-TDS B%P 3 96 5.56 9.67 10940.35 10950 22 PUP J7,4,1,2"70$L96P 3 96 5 56 9,95 10930 40 10940 35 Parker 451 SWN Nppe.w+RHC PLUG 3 73 5.23 1-50 10928 90 10930 40 PUP JT,4.17 TDS BSP ; 3 96 5 56 5.90 10923 00 10928 90 PUP Jr,4-12'7DS MP 3.96 5.56 9-83 10913 17 10923 00 Parker 4-1.r Sw$NIPPLE,T4S 3$1 5:.24 1,3T 10911,00... 10913.17 PUP JT,4-7.2 70S BAP 3.96 5.55 9.93 10901 87 10911 81C PUP JT;4 112"TOS MP 3.36 5 56 9.98 10891.89 10901 87' PUP JT,4-1)7 TOS BAP 3.96 5.50 5-90 10885.99 10991 89 LID,4-12"TDS PIN 1 5=12" NSCC BOX 3 93 6 25 .90 10.685 09 10905 99 7 r ViLLOUTEXTENSION 4.00 5.53 5-7T 10479 32 1088509 TIW 7.58"H&P PACKER 4 00, 6 58 1.05 10.674 27 10979 32 Thy LATCH ASSEMBLY 4.00 6 32 1.25 10873.02 10674.27 PUP Jr,4-1,2"TCS BEP 3.96 5 56 6.05 10866 97 10973 02 1 JT 4,1.7 TUBING •I 3 96 5.56 39.78 10827 19 10866.97 PUP JT,4-117 TDS BEP 3.96 5.56 9.99 10917 36 10927.19 PARKER a-111'SWS NPPLE. WS 3.81 5-23 1.37 10415.99 10817 38 PUP JT,4-1R'TIM REP 3,96 5,58 9,91 10806.08 10815.89 PUP jr,4.-11j'TOS 38P 3.96 5.56 9.74 10796.34 . 10806.08 1 JT 4-1/t'TURING 42 3.96 5.56 39,71 10756 63 10796.34 PUP JT,4 112"TOS BSP 3.96 5.56 9.45 10 746 68 10756 63 X-O. BTC Box X TDS Pm 3.96 5.56 1.91 10744 77 10746.68 4.I'2 MERLA Th8 X 01.1.1, w�D.rnmy 3 830 7.03 7-31 10737 46 107144 77 X-0, TDS Box X BTC Pin 3 96 5.54 1,99 10735 47 10737.46 PUP J7.4-12-TDS OSP 3.96 5.56 9.90 10725 57 10735.47 147 JTS 4 1.2'TUBING 13 4149 3.96 5.56 5.834.08 4891 49 10775 57 PUP JT 4-1)7 TDS BAP 3 96 5.56 9.86 4881 63 4891.49 X-0, 810 80c X TDS Pu' 3 96 5.56 1.91 4879 72 4881.83 4.1.2"MERL.A TMPDX GLM,w.'Dummy 3.83 7,03E 7,32 4872.40 4879.72 X.O. TDS Box X BTC Pw 3.96 5.56k 1,99 4670 41 4872.40 PUP JT,4-17 TDS BAP 3,98 5.88 9,87 4660 54 4370.41 66 JTS 4-112'TUBING 4150-1215 3 96 5 56 21813.91 2246 63 4860.54 PUP JT,4.1,2'TDB BAP 3 96 5.56 5.95 2240 68 2246.63 FLOW COUPL WG 4-1.2'TDS p.n c FOX txsx 9.88 2230 80 2210.6E £AMGO'TFIC F-4A"S�SSII.FOX WI 3 01 6 30, 6.67 2224 13 2230.00 FLOW COUPLING 4-1+2'TDS pin x FOX toc 9,38 2214,75 2224.13 PUP JT,4-12'TDS BEP 3.96 5.56 5,90 2206.95' 2214.75 55 JTS 4'1,2"TUBING 1216-1270 3 96 5 56 2172.53 36.32 2208 85 F/XTUBI NGplANC3EA1ktrPL.P 3 96 10,96' 2,32 34.00 36.32 POOL 7 Pot.TC,to Ttq Hgr LDS 34,00 34.00 _270 J11 4.1.'2", 12.64, 1-88, A9.70S Tubing 2 Oat LI1t Mandr.Is U011 p walght o1 tubing string • 190,00 f " Down welphl 61 lttln.1) : 155,0006 --....-„i - Stalnl•s. Stew Control 1I. bands a 58 Loa Paak - PUTD . 11432' . . T. .....1..._. _.I 1-_. .....F_.. 10 i • Carlisle, Samantha J (DOA) From: Loepp, Victoria T(DOA) Sent: Wednesday, August 03, 2016 1:57 PM To: Carlisle, Samantha J (DOA) Subject: FW: BP IA Cement Sundries From: Loepp, Victoria T(DOA) Sent: Tuesday, August 02, 2016 1:44 PM To: Ryan.danielCa�bp.com Subject: BP IA Cement Sundries Ryan, The following sundries for IA cementing have been submitted by BP for approval. This work requires waivers from our existing regulations.Specifically,for the production wells 20 AAC 25.200(d) requires that all producing wells be completed with suitable tubing and a packer. And for the injection wells 20AAC25.412(a) requires the well be completed with tubing and a packer and that the packer be placed with 200 ft measured depth above the perforated injection interval unless the AOGCC approves an alternate design or packer setting depth. The AOGCC is viewing your proposed work as making the existing tubing a casing string since almost the entire annulus would now be filled with cement. Therefore,the AOGCC believes the best approach is to establish pool rules that outline the criteria for when and how these types of completions can be used. We will not be approving these sundries. We recommend that BP make a request for modification to the respective Conservation Orders and Area Injection Orders and proceed through this public process. PTD Sundry Sundry Sundry PBU PTM P1-21 193-059 316-375 316-371 316-264 PBU B-31 191-046 316-399 316-368 316-270 PBU M-13A 201-165 316-376 316-369 316-259 PBU Q-06A 198-090 316-372 316-370 316-233 PBU E-07A 201-034 316-380 316-288 Regards, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.aov 1 • PTD /9 3 -0 '9 Loepp, Victoria T (DOA) From: Roby, David S(DOA) Sent: Thursday,July 21, 2016 6:19 PM To: michael.hibbert@bp.com Cc: Loepp,Victoria T(DOA); Davies, Stephen F(DOA);Wallace, Chris D (DOA) Subject: Sundry application for PTM P1-21 Well (PTD 193-059) Follow Up Flag: Follow up Flag Status: Flagged Michael, In the application it is stated"a RWO is not being progressed as we have clear evidence of leak location and otherwise integrity of the well is good." Simply knowing where a PC leak,on its own,is not sufficient justification for doing a non- conventional type of well repair instead of a conventional RWO. Please provide more justification for why this well is not a candidate for a conventional RWO repair. Thank you, Dave Roby Sr. Reservoir Engineer ,SCANNED JAN Z.7 Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.robv@alaska.gov. 1 • • 2'120-( WELL LOG TRANSMITTAL .®.II. as DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. 4 r ,. ., 5 /2S'2p1CL K BENDER MAY 23 Zi.i.., To: AOGCC o � . Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2—1 900 Benson Blvd. Anchorage, AK 99508 SCOW/ aancpdc(a7bp.com and ProActive Diagnostic Services, Inc. Attn: Diane F. Williams 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 17-Apr-16 P1-21 BL/CD 50-029-22366-00 2) Signed : Pr)✓Qget,i2e&dc/) 6....eiveft Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives1MasterTemplateFiles\Templates\Distribution1TransmittalSheets\BP_Transmit.docx • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, February 20, 2016 9:49 AM To: AK, OPS GPMA OSM; AK, OPS GPMA Field O&M IL; AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; Gerik, Bob G;Igbokwe, Chidiebere; Sauve, Mark A;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Pettus, Whitney; Sayers,Jessica; Dickerman, Eric; Sternicki, Oliver R; Regg, James B (DOA) Subject: NOT OPERABLE:Injector P1-21 (PTD #1930590) MIT-IA Failed All, Injector P1-21 (PTD#1930590) had a failing MIT-IA on February 19, 2016. The failing test proves a lack of two competent barriers and the well is reclassified as Not Operable and will be added to the Not Operable Injector report. The well shall be shut in and freeze protected as soon as possible and remain shut in pending further diagnostic work. The plan forward: 1. APE: Evaluate for LDL or secure Please call with any questions. SCANNED MAY 1 9 2016 Thank you, Kevin Parks (A!iernnte 11,17itnev Peters' BP Alaska-Well Integrity Coordinator UWelts G� Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator(cabp.com 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED · [] Logs 'of various kinds . [] Other COMMENTS: Scanned b~'~~ TO RE-SCAN Dianna Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 04, 2010 To: Jim Regg P.I. Supervisor '\~~ ~(~~,~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P1-21 FROM: Chuck Scheve PRUDHOE BAY UN PTM PI-21 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv r~P~ Comm Well Name: pRUDHOE BAY UN PTM P1-21 Insp Num: mitCS100729102458 Rel Insp Num: API Well Number: 50-029-22363-00-00 Permit Number: 193-059-0 Inspector Name: Chuck Scheve Inspection Date: 7/28/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well PI-zl Type Inj. w - TVD 8676 IA 400 2300 2260 2260 ' P.T.D~ I930590'TypeTeSt SPT Test psi 2169 OA 220 340 340 340 Intel.Va14YRTST per, P ~ Tubing 1410 1380 1450 1420 Notes: pre-test pressures were observed for 30+ minutes and found stable .,, . , Wednesday, August 04, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe.brooks@alaska.gov; tom.maurxler~a~ska.gov; doa.aogcc.pnxihce.bay~alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD t UNIT !PAD: _ Prudhoe Bay / GPMA / P1 DS DATE: 0728/10 OPERATOR REP: Jerry Murphy AOGCC REP: Chuck Scheve Packer Pretest Init~l 15 Min. 30 Min. Well P1-21 T In'. W TVD 8,676 T 1,410 1,380 1,4 ~P.T.D. 1930590 T test P Test 2169 400 2,300 2,2 Notes: MIT-IA to 2300 psi for 4 year UIC ~ OA ~ 340 3 Well P1-25 T In'. W TVD 8,750' Tubi 1,180 1,200 1,2 P.T.D. 1890410 T test P Test 2187.5 Cali 1,020 4,000 3,9 Notes: MIT-IA to 4000 psi for 4 year UIC OA 160 240 1 ~~Z 1~-gla Well T In'. TVD T Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD Tuts Interval P.T.D. T test Test P!F Notes: OA Well T In'. TVD T - ~~~~~ P.T.D. T test Test Casi P!F Notes: OA TYPE INJ Codes TYPE TEST Codes ,'~}; ~ ~ ~..tiar ~=~, ~,J t~ x~ ~, t1 ~ Li INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressun: Test 4 =Four Year Cycle I =Industrial Wastewater R = IMerr~l Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D = Dilferenfi~ Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT GPMA P1-21, 25 07-28-10.x1s NGI &LPC injector due for UIC ~ng • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, RES GPB East Production Optimization Engineer [AKRESGPBEastProductionOptimizationEngineer@bp.com] Sent: Tuesday, July 13, 2010 8:32 AM To: Maunder, Thomas E (DOA) Subject: RE: NGI &LPC injector due for UIC testing Hello Tiffany, -~3P,°_ a I assume these are the plants the State is referring to. I would take these dates as best estimates. GC1 is online now. LPC 7/14 startup GC1 Online as of 7/10 CGF Shut-down 7/15 - 8/6 Byron Jackson (alt. Ryan Rupert) GPB East Production Optimization Engineer =~~~ JUL ~. ~~ ~~~ 907.659.5923 office x2409 harmony AK, RES GPB East Production Optimization Engineer From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 13, 2010 8:25 AM To: AK, D&C Well Integrity Coordinator Cc: AK, RES GPB East Production Optimization Engineer; Brooks, Phoebe L (DOA) Subject: RE: NGI &LPC injector due for UIC testing Thanks Tiffany. What is the anticipated schedule for bringing the plants back on line? Tom Maunder, PE AOGCC From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Monday, July 12, 2010 7:34 PM To: Maunder, Thomas E (DOA); AK, D&C Well Integrity Coordinator Cc: AK, RES GPB East Production Optimization Engineer Subject: NGI &LPC injector due for UIC testing Thomas, Per our conversation, the following injectors are due for UIC compliance testing and shut in due to facility work. The wells will be put back on injection as the plants are brought back on line. Once thermally stable, we will proceed with AOGCC witnessed MIT-IA's. There are no known downhole integrity issues with any of these injectors. NGI Gas Injectors: NGI-02 (PTD #1750520) NGI-09 (PTD #1760680) NGI-14 (PTD #1780920) 7/13/2010 NGI &LPC injector due for UIC ~ing • Page 2 of 2 LPC SWI injector: P1-21 (PTD #1930590) ~--~--- Please contact Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Gerald Murphy/Toxin Roschinger) Projects Well Integrity Engineer phone: (907) 659-5102 cell: (253) 576-6153 tiffg0@bp.com 7/13/2010 • BP Exploration (Alaska) Inc. Attn: Well Integrity coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 by January 1, 2010 "~~'~~~~'~ '~~`~ $ ~ ~ ~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~~3~ d 333 West 7t" Avenue I Anchorage, Alaska 99501 P Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-06 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-08A 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA 6.80 7/7/2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13!2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 PI-2I (PTD #1930590) Increase in IA Pressure . All, Well P1-21 (PTD #1930590) has been found to have high IA pressure. The TIO pressures were 1953/1800/375 on 04/19/07. The increase in IA pressure is thought to be due to the increased injection rate and thermal effects. /<} J __/7 .. 4f I V&-v.,JU' 11 Dh '( ~ >Zi) () 7 ~ k~c,,- ~k BP I The plan forward for this well is as follows: 1. DHD: Bleed lAP, monitor for build-up rate 2. WIE: After evaluating BUR data, determine if a MITIA needs to be conducted. A TIO plot and an injection plot have been included for reference. «P1-21 TIO Plot.BMP» «P1-21 Injection Plot.BMP» A wellbore schematic has been included for reference. «P1-21.pdf» Please call if you have any questions. Thank you, jInna (])u6e, œ. P.. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 sCANNED APR 302007 Content-Description: Pl-21 no Plot.BMP Pl-21 TIO Plot.BMP Content-Type: imagelbmp Content-Encoding: base64 Content-Description: Pl-21 Injection Plot.BMP Pl-21 Injection Plot.BMP Content-Type: imagelbmp Content-Encoding: base64 I of 2 4/23/2007 II :42 AM Pl-2I (PTD #1930590) Increase in IA Pressure . 2of2 . Content-Description: Pl-21.pdf Content-Type: application/octet-stream Content-Encoding: base64 4/23/2007 I I :42 AM Plot8M? 830x283 ¡ of ( If·iHiP AM P}-21 no Plot8MP 830x283 AM FMC CrN AXELSON 50' 46 (â) 3362' 11092' 8800' SS 10-3/4" CSG, 45.5#. J-55. 10 = 9.953" I Minimum ID = 3.725" @ 10929' 4-1/2" PARKER SWN NIPPLE 4-1/2" TSG, 12.6#. L-80. 0.0152 bpf. 10 = 3.958" I 1 0953' PERFORA TION SUMMA RY REF LOG: DPR/NEU/DENS ON 05/05/93 ANGLE AT TOP PERF: 37 @ 11102' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 11032 - 11042 0 09/23/04 3-3/8" 6 11050 - 11090 0 09/23/04 3-3/8" 6 11102 - 11112 0 02/05/94 3-3/8" 4 11124 - 11134 0 05/13/93 3-3/8" 4 11151 - 11168 0 05/13/93 3-3/8" 6 11170 - 11190 0 02/05/94 3-3/8" 4 11191 - 11251 0 05/13/93 3-3/8" 4 11271 - 11361 0 05/13/93 3-3/8" 6 11375 -11400 0 07/18/03 I PBTD I 11513' 11432' 7-5/8" CSG, 29.7#, NT-95, ID = 6,875" I DATE 05/10/93 08/12/01 07/18/03 06/25/04 09/23/04 OA TE REV BY P1-21 . COMMENTS NOTE: TBG HNGR: FMC BPSH @ 34' MD. 2224' - 4-1/2"CAMCOTRCF-4ASSSV.ID=3.812" I GAS LIFT I'v1ANDRELS ST MO TVO DEV TYÆ LV LATCH POR DATE 1 4872 4165 43 TE- TMPDX BK 2 10737 8568 39 TE- TMPDX BK 10816' - 4-1/2" PARKER SWS NIP, ID = 3.813" I 10874' H 7-5/8" X 4-1/2" TrN HBSP PKR, ID = 4.00" I 10912' - 4-1/2"PARKERSWSNIP.10=3,813" I 10929' -! 4-1/2" PARKERSWN NIP. 10 = 3,725" I 10952' -! 4-1/2" TBG TAIL WLEG, 10 = 4.00" I 10935' H ELMD TT LOGGED 02105/94 I POINT I\¡ICINTY RE UNff WELL: P1-21 ÆRMff No: 1930590 API No: 50-029-22363-00 Sec. 16, T12N, R14E, 5149.72 FEL 2894.96 FNL BP Exploration (Alaska) MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor )/." . -j ---I V (/¿,/ i '7:-"i. !"'--- ~'{<-{ . I ~/j ¡U,? DATE: Wednesday, July 05, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PI-21 PRUDHOE BA Y UN PTM PI-21 Src: Inspector '3/0&\ \'\ Reviewed By: P.I. Suprv :f¡3~ Comm FROM: Lou Grimaldi Petroleum Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN PTM PI-2l API Well Number 50-029-22363-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060702141347 Permit Number: 193-059-0 Inspection Date: 7/2/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i PI-21 !Type Inj. I W TVD 8676 I IA ! 670 I 2300 I 2270 2255 I ! ! I I ! P.T. i 1930590 ITypeTest ! SPT Test psi 2300 ! OA 100 I 180 180 180 ! 1 ! i I t--'~ Interval 4YRTST P/F P Tubing I 1260 I 1280 I 1260 1260 I I Notes 4.0 bbl's pumped, Good Test ;"'C<!:'A~~'1"'~~~iÍ ....;; __~f~ t:.. \h....¡,~.· '" ,. ç,..' ....·0;. Wednesday, July 05, 2006 Page 1 of 1 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D ALASKA)OIL AND ~~;~g~S~~;At<.;;ON COM~ISSION ; REPORT OF SUNDRY WELL OPERATION@fT 262004 Mlaska 001 & G~.:" Stimulate D Oth¡U ,. [DUma WaiverD Time Extension .. Re-enter Suspended Well 0 5. Permit to Drill Number: 193-0590 6. API Number 50-029-22363-00-00 Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate [K) 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development D 50.00 8. Property Designation: ADL-034622 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: P1-21 10. Field/Pool(s): Pt Mcintyre Oil Field / Pt Mcintyre Oil Pool ExploratoryD Service ŒJ Total Depth measured 11525 feet true vertical 9201.9 feet Effective Depth measured 11403 feet true vertical 9102.0 feet Plugs (measured) Junk (measured) None None Casing Conductor Production Surface Length 80 11475 3980 Size 20" 91.5# H-40 7-5/8" 29.7# NT-95 10-3/4" 45.5# J-55 MD TVD Burst Collapse 470 5120 2090 41 121 41.0 121.0 38 - 11513 38.0 - 9192.1 40 - 4020 40.0 - 3550.2 1490 8180 3580 Perforation depth: Measured depth: 11032 -11042,11050 -11090,11102 -11112,11124 -11134,11151 -11168,11170 -11190,11191 -11251 11271 - 11361, 11375 - 11400 True vertical depth: 8801.54 - 8809.55,8815.96 - 8848.05,8857.69 - 8865.72,8875.35 - 8883.38,8897.06 - 8910.77,8912.38 - 8928.52 8929.32 - 8977.84,8994.07 - 9067.58,9079.04 - 9099.52 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 35 10955 Packers & SSSV (type & measured depth): 4-1/2" Camco TRCF-4A SSV 4-1/2" TIW HBBP Packer @ 2225 @ 10875 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0 -12851 700 0 -16288 500 SCANNED Nn\l n ~ 2004 13 Prior to well operation: Subsequent to operation: Oil-Bbl 0 0 Tubing Pressure 1696 2028 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations - ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ Signature Garry Catron Garry Catron .):1~ Ce;~ WAG D GINJD WINJŒ] WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 1 0/18/04 OR\G\NAL _ef~ \{.\ ~ 1 - Form 10-404 Revised 4/2004 ') ) P1-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09108/04 *** WELL ON INJECTION ON ARRIVAL *** (PRE ADD PERF). RAN FLAPPER CHECKER, OK. HAD TO EVACUATE PAD, DSO NOTIFIED, PERMIT TURNED IN. **** WELL LEFT SHUT IN **** 09/17/04 (WELL INJECTING ON ARRIVAL). DRIFT WI 3318 DUMMY GUN TEL SB I PRE ADD PERF. TAG TD @ 11387' CORR TO ELM ( 131 FILL). RDMO. (LEFT WELL SHUT IN PAD OP. WILL POI) 09/23/04 ADD PERFORATIONS WITH 3-31811 GUNS 6 SPF HSD 3406 PJ HMX INTERVAL 11070 - 11090 FT - GOOD INDICATIONS AT SURFACE OF FIRING- RETURNED GUNS HAD ALL SHOTS FIRED INTERVAL 11050 - 11070 FT - GOOD INDICATIONS AT SURFACE OF FIRING FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL Page 1 ) 1REE = FtvC WELLHEAD = ŒN ACTUA "fOR-;-----AXB..SON 1<B:-ä:BJ -;;-----"----- 50' """""""',^,,",,"""""""'"-""'""'~"~~~~_^~~^^A^~^,"^""""""- BF. B..EV = ~,~---""~,,,,,,,,,,,,,,~,,,,,,,,,,,~'W""^"^""'^"".""..'W.,",,,,~~..^"^'v.o.o.c KOP = 1289' Max Angle = 46 @ 3362' . i)3tüïñ"""fVö;;"'""" "'""'."""'""'"1"fö 92' '[>ãtuiñ".iVÖ"";"""""""""." """""Sãoõ"ï"ss' 10-3/4" CSG, 45.5#, J-55, ID = 9.953" H 4020' Minimum ID = 3.725" @ 10929' 4-1/2" PARKER SWN NIPPLE 4-1f2" TBG, 12.6#, L-80, 0.0152 bpf, ID= 3.958" H 10953' 1 PERFORATION SLlv1MA.RY REF LOG: DffilNEUIDENS ON 05/05/93 ANGLE A TTOP PERF: 37 @ 11102' I'bte: Refer to A"oductbn œ for historical perf data SIZE SPF IN1£RVAL Opn/Sqz DATE 3-318" 6 11102-11112 0 02/05/94 3-318" 4 11124-11134 0 05/13/93 3-318" 4 11151 - 11168 0 05/13/93 3-318" 6 11170 - 11190 0 02/05/94 3-318" 4 11191-11251 0 05/13/93 3-318" 4 11271-11361 0 05/13/93 3-318" 6 11375-11400 0 07/18/03 1 PBTD H 11432' I 7-5/8" CSG, 29.7#, NT-95, ID = 6.875' H 11513' DA. TE REV BY COMMENTS 05110193 ORIGINAL COMPLETION 0212010 1 SIS-MD RNAL 08112101 RNIfP CORRECTIONS 07/18103 BJM;UTLH ADD PERF 06125104 RAP/KAK FERF CORREC1l0NS P 1-21 e ~ L I :g z= I I ; I~ DATE REV BY COMMENTS ) SAFETY NOTE: TBGHNGR: RIIIC BPsH@ 34' MD. 2224' H 4-112" CAMCOTRCF-4A SSSV, ID=3.812" 1 ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DA.1£ 1 4872 4165 43 1£- TMPDX BK 2 10737 8568 39 1£- TMPDX BK I 10816' H 4-1/2" PARKERSWS NIP, ID =3.813" 1 I 10874' H 7-5/8" X4-1/2" TIW HBBPPKR, ID = 4.00" I 1 10912' 1--1 4-1/2" PARKERSWS NIP, ID =3.813" I I 10929' H 4-1/2" PARKER SWN NIP, ID = 3.725" 1 1 0952' - 4-1/2" lBG TAL WLEG, ID = 4.00" 1 10935' - B..MD TT LOGGED 02105/94 I I I I I POINT MaNlY RE UI\IT WB..L: P1-21 ÆRMIT No: 1930590 API No: 50-029-22363-00 Sec. 16, T12N, R14E, 5149.72 FB.. 2894.96 Ff\1. BP Exploration (Alaska) 'L STATE OF ALASKA ALAS OIL AND GAS CONSERVATION C ,.MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanon~--~ Suspendr'-~ Operation ShutdownE~] Perforate, Variancer-~ Annuar Disposal[~ After Casin.a[--I Repair Well[ '] Plu~3 PerforationsD Stimulate[-] Time Extension[--] Other[-] Change Approved Program r"l Pull Tubing r-] Perforate New Pool r"'l Re-enter Suspended Well E~ ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [--] Exploratory[~ 193-059 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic [~ Service, 50-029-22363-00-00 7. KB Elevation (ft): 9. Well Name and Number: 35.00 P1-21 8. Property Designation: 10. Field/Pool(s): ADL 034622 Prudhoe Bay Field ! Point Mclntyre Oil Pool 11. Present Well Condition Summary: Total Depth measured 11525 feet true vertical 9202 feet Plugs (measured) Tagged TD @ 11403 (06/15/2003). Effective Depth measured 11403 feet Junk (measured) true vertical 9102 feet Casi n g Lan gth Size M D TV D B u rst Col laps e Conductor 80' 20" 120' 120' 40K 520 Surface 3980' 10-3/4" 4020' 3550' 80K 2480 Production 11473' 7-5/8" 11513' 9192' 80K 4790 Perforation depth: Measured depth: Open Perfs 11102'-11112', 11124'-11134', 11151'-11168', 11170'-11190', Open Perfs 11191 '-11251 ', 11271 '-11361 ', 11397'-11422'. True vertical depth: Open Perfs 8858'-8866', 8875'-8883', 8897'-8911 ', 8912'-§929',. Open Perfs 8929'-8978', 8994'-9068', 9097'-9118'. '.... ~ ~.~ .,.,..,, ...... ,. ,,~ .,, ~ ..,.,. Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 10953'. ,,,...~,,.,,. ~..~ ...... , ..... Packers & SSSV (type & measured depth) 7-5/8"x4-1/2" TIW HBBP PKR @ 10874'. 4-1/2" Camco TRCF-4A SSSV @ 2224'. ~,.. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 15078 1601 Subsequent to operation: 15972 1790 14. Attachments: 15. Well Class after proposed work: ExploratoryE] DevelopmentD Service~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: OilE] Gasr"] WAGr'-~ GINJD WINJ[] WDSPLE] Daily Report of Well Operations _X '17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. schnorr I N/A Printed Name DeWayne R. Schnorr __ ,, Title Techical Assistant Signature ~~,,-,,_e~ ~ Phone 907/564-5174 Date Sept 24, 2003 Form 10-404 Revised 2/2003 P1-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/14/2003 PERFORATING: DRIFT/TAG 06/15/2003 PERFORATING: DRIFT/TAG 07/18/2003 PERFORATING: PERFORATING 09/22/2003 TESTEVENT--- INJECTION PRESSURE, PSI: 2,292 TYPE: SW VOLUME: 21,236 BWPD. EVENT SUMMARY 06/14/O3 FOUND WELL ON WATER INJECTION ON ARRIVAL. BEGIN RIGGING UP. CONTINUE WSR ON 6/15/03. JOB IN PROGRESS. 06/15/O3 DRIFT W/3-3/8" DMY GUN, TEL, & SB -- LOCATE EOT @ 10,918 SLM (10,935' ELMD). TAGGED TD @ 11,384' SLM (CORRECTED TD @ 11,403') (TARGET -- 11,410). <<< SAMP BLR HAD HEAVY SCHMOO >>> <<< DSO WILL PUT WELL ON INJECTION >>> 07/18/03 CORRLEATION LOG (FOR POSSIBLE FUTURE PRIMARY DEPTH CONTROL) AND PERFORATION RUNS. GUN #1 LOADED 10 FEET WITH 3406 POWERJETS AT 6 SPF. CORRELATION LOG TAG DEPTH - 11422 FT MD. GUN #1 TD TAG DEPTH - 11402 FT (REFERENCED TO THE CBT LOG DATED 13-MAY-1993). GUN #1 INTERVAL = 11390-11400 FT MD (RIGHT AT BOTTOM). GUN #2 = 15 FEET LOADED IN 20 FOOT STOCK. GUN #2 TAG DEPTH -- 11405 FT MD. GUN #2 INTERVAL = 11375-11390 FT MD. <<< WELL LEFT SHUT IN, BUT READY FOR INJECTION >>> 09/22/03 TESTEVENT--- INJECTION PRESSURE, PSI: 2,292 TYPE: SW VOLUME: 21,236 BWPD. FLUIDS PUMPED BBLS 2 IPUMPED DIESEL FOR PRESSURE TEST. (2 TESTS) ADD PERFS 07/18/2003 THE FOLLOWING INTERVAL WAS PERFORATED WITH 3-3/8" 3406PJ POWERJET GUN, LOADED AT 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 11397'-11422' Page I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair DATE: July 2, 2002 THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX Pt. Mac 1 P1-14, 16, 21, 25 PBU Pt. Maclntyre Field Packer Depth Pretest Initial 15 Min. 30 Min. I WellI P1-14 ITypelnj. I S J Ti'V.D. I 83211Tubingl 2350 I 2350 J 2350 I 2350 JlntervalI 4 J P.T.D.I 1930160 TypetestI P. ITestpsiI 2080 I Casing} zero J 2140J 21101.2,100I P/F J P } Notes: Pre-test pressures monitored 15 min. & stable. I P.T.D.I 1930340 ITypetestI P JTestpsiI 2194 I CasingI zero } 2240 I' 22101 2210} p/F } ~ Notes: Pre-test pressures monitored 15 min. & stable. .... WellI P1-21 ITypelnj. I S J T.V.D. J 8676 I Tubing~ 1850 I 1850 I 1850 I 1050 Ilnte~all 4 P.T.D.I 1930590 {TypetestI P ]Testpsi{ 2169 I Casingl zero '{ 2380 I~ 2350 I 2350 I P/F ] ~ Notes: Pre-test pressures monitored 15 min. & stable. WellI P1-25 ~Typelnj. l' S I T.V.D. I 8751 I Tubingl 400 I 380 I 380 I 380 I lnte~all 4 P.T.D.I ~904~0 TypetestI p ITes~ps, I 2~88 I Cam, I 200 I 228O I 2~65. I 22~S I P/F I ~ Notes: Pre-test pressures monitored 15 min. & stable. F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details July 2, 2002: I traveled to BPX's PM-1 Pad to witness 4 year MITs on water injection wells Pl-14, PI-I6, P1-21 and P1- 25 in the Pt. Maclntyre Field. Roland Johnson was the BPX representative in charge of testing today and he performed the task in a safe and proficient manner. The pre-test pressures were monitored for 15 min. and were found to be stable. The standard annulus pressure test was then performed on each well, with all four wells passing the MITs. Summary.: I witnessed successful MITs on BPX's water injection wells Pl-14, Pl-16, P1-21 and P1-25 in the Pt. Maclntyre Field, PBU. M.I.T.'s performed: 4_ Number of Failures: 0_ Total Time during tests: Attachments: cc: SCANNED AUG 0 1 2002 MIT report form 5/12/00 L.G. M IT PBU Pt Mac 1,14,16,21,25 7-2-02 JJ 1 .xls 7/18/2002 AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA_PLUS Page' 2 Date' 04/04/95 RUN DATE_RECVD Was the well cored? yes'~o/~'~ Analysis & description rece~d?._ Are well tests required? yes ~ Received? ,~es no Well is in compliance I" ~~~±al COMMENTS yes no ARCO Alaska Inc. Greater Point McIntyre Engineenng Date: Subject: From: September 29, 1994 Transmittal Number ARCO Alaska, Inc. 745 To: Bob Crandall AC)GCC 3001 Porcupine Drive Anchorage, AK 99501 The following Greater Point McIntyre Area data are enclosed. and your cooperation in maintaining confidentiality is appreciated: Well Name Data Description L3-01 .....Tubing Puncher Record '~'Xa RAB-Final ~L) ~ ~Bit and Ring Resistivity ~ ~DR-Final L.~6'~ C~R-Very Enhanced Resistivity-Gamma Ray ~, ~rue Vertical Depth CDR-Final ~I~1 Injection Profile Log (Press-Temp-SPIN-GR) P~6 Perforation Record 2-~/8" Phased E~ 6 SPF ~-07 Perfora~g Record wi~ GR/CCL Jewe~ Log Perfora~on Record 3-~/8" HSD 41B ~ 6 SPF _~2-18/ Perfora~g Record wi~ GR/CCL Jewe~ Log ~2-18 . Stafifi Pressure Survey-Press-Temp ~2-21 Perfora~on Record 3-3/8' HSD 4lB ~ 6 SPF Tr~s~al N~ber: 745 Page: This information i~ 'c~nfidential 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 1 8/23/94 Schlumberger 1 8/23/94 Schlumberger I 7/27/94 Schlumberger 1 7/27/94 Schlumberger 1 7/21/94 Schlumberger 1 7/25/94 Schlumberger 1 7/25/94 Schlumberger I 7/22/94 Schlumberger 1-12 3/6/94 Schlumberger Run # Date Run Company 1 9/6/94 Schlumberger STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS · Operations performed: Operation shutdown Pull tubing __ Stimulate __ Plugging __ Perforate Repair well __ Alter casing __ Other x.~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1379' NSL, 923' WEL, Sec 16, T12N, R14E At top of production interval 2103' NSL, 46'EWL, Sec 10, T12N, R14E At effective depth 2103' NSL, 46'EWL, Sec 10, T12N, R14E At total depth 2383' NSL, 114'EWL, Sec 10, T12N, R14E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service x_._ 16. Datum elevation (DF or KB) RKB=35' 7. Unit or Property name Point Mclntyre 8. Well number P1-21 9. Permit number/approval number 93-59 /94-151 10. APl number 50-029-22363-00 11. Field/Pool Prudhoe Bay/Point Mclntye feet 12. Present well condition summary Total Depth: measured: true vertical: 11525 feet Plugs (measured) None. 9202 feet Effective Depth: measured: 11432 feet Junk (measured) None. true vertical: 9126 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 281 cu ft Arcticset 80' 80' 3980' 10-3/4 2387 cuft PF "E"/402 cu 4020' 3550 Surface ft "G" Intermediate 11473' 7-5/8 667 cu ft Class "G" 11513' 91 92 Liner Perforation depth: measured 11102-11112', 11124-11134', 11151-11168', 11170-11190', 11191-11251', 11271-11361' true vertical 8858-8866', 8875-8883', 8857-8911', 8912-8928', 8929-8978', 8994-9068', Tubing (size, grade, and measured depth) 4-1/2'' 12.6# L80 @ 10954' Packers and SSSV (type and measured depth) CECEIVED Pkr. @ 10874', TRCF-4A SSSV @ 2224' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A A1 .... ~,, 0ii & 6as Cons. Commission Anchor~ ...~ 14. 15. Prior to well operation Subsequent to operation Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations _._x .Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure MiT 4935 3418 405 2130 on a/I n/a n/a 7944 2 0 16. Status of well classification as: Oil Gas Suspended Tubing Pressure 693 1122 17. I hereby certify that the foregoing is trueand~¢orrect to the best of my knowledge. , Form 10-404 [:lev 0~/15/88 Service x SWI Date September 22, 1994 SUBMIT IN DUPLICATE P1-21 Daily Report of Well Operations 07/15/94 P1-21 SI @ 1955 HR FOR DS P2 START UP AND LPC SHUT DOWN 07/17/94 P1-21 DSM PULLED A/L SPOOL AND HOOKED UP FLOWBACK. WIRELINE ON WELL SINCE 1630 OR SO 07/19/94 WIRELINE PULLED PLUG ON P1-21. SHOULD BE READY FOR MIT WHEN HARDLINE STUFF IS RIGGED DN. 9 5/8 VALVE IS SHUT. 07/20/94 07/21/94 P1-21 STATE WITNESSED MIT COMPLETED, PASSED. PANEL WAS DUMPED, PUMPED PANEL. DIDNT OPEN SSSV. Pl-16 & P1-21 BLED ANN. FROM 2000+ TO 1300 PSI P1-14,16 & 21 WATER METERS SEEM TO BE WORKING & LPP'S SET @ 75 PSIG WERE INSTALLED ON DOWNCOMERS... 07/23~94 P1-21 STARTED WATER INJECTION. P1-14,16 & P1-21 ARE ALL INJECTING WATER, RATES ON 14 & 16 ARE NOT MAKING IT TO SETCIM. NEED A NEW 75~ LPP ON P1-21 07/24/94 WATER INJACKSON INCREASED TO 4000 BPD AT 0830 HRS. 14,16,21 NOW READ. RECEIVED Gas Cons. Comrnission OPERATOR: ARCO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test - , FIELD l UNIT/PAD:...__._ PT. McINTYRE/PBU/Pf.~ DATE: ..~:;~:it~,.;i * : ,.~ :. COMMENTS: This w~il is being convetfed to an inJecfor. This is the initial MIT. COMMENTS: COMMENTS: COMMENTS: *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S · SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING ~ - Well File c- c - Trip Rpl File c - Inppec~ol RECEIVED SZP 2 7 ~994 .~-,,~:,-,~ -,: & Gas Cons. Commission A,qch0 r~., ~ ANNULAR FLUID: P.P.G. Grad. WELL TF. ST: DIESEL I In#Iai GLYCOL 4 - Year SALT WATER ' Workover_ DRILLING MUD Other OTHER I AC)GCC REP: OPERATOR REP: X Jerry ~ John Hentlles STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing __ Change approved program x Pull tubinc~., 2. Name of Operator ~5. / ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510 Suspended __ Operation Shutdown __ Repair well __ Plugging __ Variance Type of Well: Development Exploratory __ Stratigraphic w Service ~x 4. Location of well at surface 1379' NSL, 923' WEL, Sec 16, T12N, R14E At top of production interval 2103' NSL, 46'EWL, Sec 10, T12N, R14E At effective depth 2103' NSL, 46'EWL, Sec 10, T12N, R14E At total depth 2383' NSL, 114'EWL, Sec 10, T12N, R14E Re-enter suspended well Time extension Stimulate Perforate Other 6. Datum elevation (DF or KB) RKB=35' 7. unit or Property name Point Mclntyre 8. Well number P1-21 9. Permit number 93-59 10. APl number 50-029-22363-00 1 1. Field/Pool Prudhoe Bay / Point Mclntye feet 12. Present well condition summary Total Depth: measured' true vertical' 11 525 feet 9202 feet Plugs (measured) None. Effective Depth: measured: 11432 feet true vertical: 9126 feet Casing L e n g t h Size Ce m e n ted Conductor 80' 20" 281 CU ft Arcticset 3980' 10-3/4 2387 cu ft PF "E"/402 cu Surface ft "G" Intermediate 1 1473' 7-s/8 667 CUft Class "G" Junk (measured) None. Measured depth True vertical depth 80' 80' 4020' 3550 11513' 9192 Liner Perforation depth: measured 11102-11112', 11124-11134', 11151-11168' 11170-11190', 11191-11251' 11271-11361' true vertical 8858-8866', 8875-8883', 8857o8911', 8912-8928', 8929-8978', 8994-9068', Tubing (size, grade, and measured depth) 4-1/2" 12.6# L80 @ 10954' Packers and SSSV (type and measured depth) Pkr. @10874', TRCF-4A SSSV @ 2224' 13. Attachments RECEI Description summary of proposal x Detailed operation program jdN ] ~ Udb BOP sketch~-'-~;''j bil Cui~: -- Conved well from Oil Production to Water Injection. Anchora§ 14. Estimated date for commencing operation June 27, 1994 15. Status of well classification as: Oil __ Gas __ Suspended 16. If proposal was verbally approved Name of approver Date approved service Water Injector 17 I~/certi~t~(./t~he foregoing !s true and correct ,o the best of my knowledge. /__ s~~/''//.//_~.~ ¢' ~//./-~',~'~ ~/.///7,/¢..~.~enda S. Wylie Title GPMA Sr. Engineer Date~~. ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP test ~ Location clearance -- Mechanical Integrity Test,~ ,Subsequent for required 10- original Signed By Approved by order of the Commission 08vid W_ .10h.n. st0.n. Commissiolqer Approval ~.~ --r ,~/ Date ED 994 Gommissior Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE Attachment I Conversion to Water Injection Point Mclntyre P1-21 ARCO Alaska requests approval to convert Well P1-21 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order 4A. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 11102' and 11361' measured depths This interval con'elates with the strata found in ARCO's Point Mclntyre Well No. 11 between the measured depths of 9908' - 10665' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED /.~ .... ~'" Oil & Cas Cor~s. f3r;~mrnlssic,, A~ch0ra~e Date: Subject: From: To: -;-' ARCO Alaska Inc. Grea~..~ Point Mclntyre Engineering April 19, 1994 Transmittal Number ARCO Alaska, Inc. Bob Crandall AC)GCC 3001 Porcupine Drive Anchorage, AK 99501 72O The following and your cooperation in maintaining confidentiality is appreciated: NK-26 FINAL DISKE~: MWD w/Sub-Surface 3-17-94 qq~o~ Directional Survey efo~" (Z) Greater Point McIntyre Area data are enclosed. This information is confidential Pl-17 "/FINAL LOG: Production Profile 1 3-7-94 ./ P1-21 ~' FINAL LOG: Perf Record 3 3/8" HSD - 6 SPF 1 2/5/94 P2-06 P2-06 P2-06 P2-12 P2-12 P2-15 P2-15 P2-15 ~F]2'4AL LOG: Perforation Record 2 1/8" Phased 1 Enerjet ~'4AL LOG: Static Pressure Survey 1 Press-Temp-Gr / CCL FINAL DISKET~: GCT -Surface 1 w/S jo Directional Survey 4- ~~ /FINAL LOG: Perf Record 3 3/8" HJI[, 6 SPF 1 / '"FINAL LOG: Static Pressure Survey 1 Press-Temp-Gr/CCL ~4AL TAPE: DIFL/CN/ZDL/GR w/LIS Ver I 1/30/94 1/31/94 Anadrill Schlumberger Schlumberger Schlumberger V/FINAL LOG: Sub-Sea Vertical Depth (MWD 1 Directional Survey) V~FINAL LOG: Borehole Profile 1 Schlumberger 1-7-94 Schlumberger ~/FINAL LOG: Z-Densilog Comp NEUTRON GR/Caliper 1/29/94 P2-15 1129/94 Schlumberger Schlumberger 3-5-94 Atlas 3-5-94 Atlas 3-5-94 1 3-5-94 Atlas Wireline Atlas . -i~N.N~.~.tN~ Well Name P2-15 P2-15 P2-15 P2-15 P2-15 P2-16 P2-t6 P2-23 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 Data Description "F/INAL LOG: Dual Induction Focused Log GR/SP FINAL DISKETTE: MWD Survey w/LIS Ver FINALLOG: Cement Evaluation (CET-GR) FtNALLOG: Cement Bond Log (CBT-GR) ~FtNAL DISKETTE: GCT w/Sub-surface Directional Survey LIS Ver INAL LOG: PerforatSn§ Depth Control Powered Gun GR ~'4AL LOG: Perforation Record 3 3/8"HJ II, 6 SPF ~/FINAL DISKETTE?MWD Survey w/LIS Ver CFINAL TAPE: DIFL/CN/ZDL/GR w/LIS Ver 1 /FINAL LOG: Borehole Profile v/FINAL LOG: Sub-Sea Vertical Depth (Directional Drillers Data) d/FINAL LOG: Z-Densilog Comp NEUTRON GR/Caliper '/'FINAL LOG: Dual Induction Focused Log 1 GR/SP '~INAL DISKETTE' ~-~ Survey w/LIS Vet / X,,FINAL DISKETTE' Electronic Multi-shot Survey w/LIS Vet · v~FINAL LOG: Cement Evaluation Log (CET-GR) Run # 1 Date Run 3-5-94 3-9-94 3-26-94 3-26-94 3-26-94 1/26/94 1/27/94 3-23-94 2/12/94 2-12-94 2-12-94 2-12-94 2-12-94 2-10-94 2-10-94 3-25-94 Company Atlas Sperry Sun Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Sperry-Sun ATLAS Atlas Atlas Atlas Atlas Sperry-Sun Sperry Sun Schlumberger Transmittal Number: 720 Page: 2 · Well Name P2-29 P2-29 P2-30 P2-30 P2-30 Data Description V(~AL LOG: Cement Bond Log (CBT-GR) Run # 1 V/FINAL DISKETTE:_ _Sub_-.Sj;Lrface Directional Survey (GCT) ~ ',/FINAL TAPE: CH Edit 3 Pass CNT-G with 1 Average Pass w/Ver List / ./FINAL TAPE: CH Edit TDTP 3 Passes and 1 Average w/Ver List LOC.. ' e.~'l'- ~ ] ~C.. V/FINAL LOG: TDTP Depth Corrected 1 Date Run 3-25-94 3-20-94 1-8-94 1-8-94 12-8-93 Company Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger P2-31 P2-31 P2-31 P2-31 P2-31 P2-31 P2-42 P2-42 P2-42 P2-42 P2-42 /FINAL DISKETTE: MWD w/Sub-Surface Directional Survey ?-~.~ ~'/v~A~~TTE: Electronic MultiShot w/LIS - '/FINAL LOG: Sub Sea VD (Multi-shot 1 Directional Survey) INAL LOG: Dual Laterolog/GR/SP 1 FINALLOG: Borehole Profile FINAL LOG: Z-Densilog / Comp Neutron / GR / Caliper ~2qAL LOG: Dual Induction Focused Log/GR/SP '/FINAL LOG: Formation Multi-Tester/GR V/FINAL LOG: Sub-Sea Vertical Depth (MWD Directional Survey) V/FINAL LOG: Z-Densilog/Compensated 1 N eu tron/ G R / C alip er /'FINAL LOG: Borehole Profile 1 04-08-94 4-10-94 4-10-94 4-10-94 4--10-94 4--10-94 1/9/94 1/9/94 1/9/94 1/9/94 1/9/94 Sperry Sun Sperry Sun Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Atlas Atlas Atlas Atlas Transmittal Number: 720 Page: 3 Well Name Data Description P2-42 '/'FINAL DISKETTE: MlffD Survey w/LIS Vet P2-51 v/~AL LOG: TDTP Depth Corrected l P2-51 ~INAL TAPE: CH Edit 3 Pass TDTP w/Average Pass w/Vet List ,, / P2-51 ~INAL TAPE: CH Edit 3 Pass CNTG and Average w/Vet List P2-57 V~FINAL LOG: 2.5" CNT-~'>Depth Corrected P2-57 FINAL TAPE: CH Edit 2.5 CNT-D 3 passes w/Average w/Vet List Run # Date Run Company 1/8/94 Sperry-Sun 1-11-94 Schlumberger 1-11-94 Schlumberger 1-11-94 Schlumberger 11-14-93 11-14-93 Schlumberger Schlumberger Please sign /~_.. &~_;~2 and return Elizabeth R. Barker, ATO-415 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal Number: 720 Page: PERMIT 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 93-059 DATA 5925 AOGCC Individual Geological Materials T DATA_PLUS (~ OH-DPR,6894-11525 6361 T 14805-15604 CN/GR/MAC/GR 407 ~ COMP DATE'05-17-93 DAILY WELL OP. FINAL WELL SURVEY SURVEY BD/GR (MD) CBT DRILLING HISTORY SUB-SURFACE ~SS DIRECTIONAL 5",R3-6,6689-11513 ~--10600-11700 DP/NP/DPR/GR(MD) ~/L 2&5",R3-6,6689-11513 DP/NP/DPR/GR(TVD~L 2&5",R3-6,6689-11513 DP/NP/GR(MD) DP/NP/GR ( TVD ) DPR/GR (MD) DPR/GR (TVD) EXLOG-EPT (MD) EXLOG-IFT (MD) EXLOG-IFT (TVD) EXLOG-PDT (MD) GCT PERF PERF PRESS/TEMP/SPIN 2&5",R3-6,6689-11513 2&5",R3-6,6689-11513 2&5",R3-6,6689-11513 2&5",R3-6,6689-11513 ~'8000-11525 ~' 8000-11525 ~ 8000-I1525 6500-9200 LL~0000-11334 10900-11375 10850-11300 11000-11280 PROD/FBS/TEMP/PR ~-"/i1000-11340 GCT ~"~' RUN 1 Well Inventory Page' 1 Date' 04/04/95 RUN DATE_RECVD 3/6 12/06/1993 1 12/08/1994 07/09/1993 07/09/1993 11/19/1993 06/24/1993 07/09/1993 08/23/1993 06/24/1993 08/23/1993 08/23/1993 08/23/1993 08/23/1993 08/23/1993 08/23/1993 11/19/1993 11/19/1993 11/19/1993 11/19/1993 06/24/1993 06/24/1993 1 04/19/1994 1 09/29/1994 1 03/11/1994 06/24/1993 Date: Subiect: From: To: ARCO Alaska Inc. Greater Point McIntyre Engineering March 7, 1994 Transmittal Number 703 ARCO Alaska, Inc. Bob Crandall AOGCC 3001 Prokupine Drive Anchorage, AK 99501 The following Greater Point McIntyre Area data are enclosed. and your cooperation in maintaining confidentiality is appreciated: fP1-05 t/ST1 k, P1-05 ~/ST1 P1-08 tP1-08 S 1-08 TI P1-20 q P1-21 F2-06 Final Log: CDR__~_3Je~v Ep_h_anced Resis~vi~ L~th Corrected~ Final Log: C~R LWD/Depth Corr_L~ected Final Log: CDN LTD/Depth Corrected %tq oo -- ~5%oo FINAL Log: CDR* Very Enhance_.~d Ro.~i.~tivity FINAL Log: ~rue Vertical Depth~X2DR, Tape: ~ Edit~~~Ordy in 5 bit runs w/Verification Listing Tape: ~ Edit ~n 2 ST bit runs (with original Well) LDWG Format Pr_o~ductio__n Log: FBS / TEM'P / PR ES.~ / GRADIO/_IL-II JM Eroducl:ion Ll)g: Log: P_r. oduction Log FB.~S./Temp/Press _/Gradio/HUM This information is confidential ~) 7/8-9/93 Schlumberger / Izq ~o-- J %~0 5 7/8-9/93 Schlumberger / (~) ' 7/8-9/93 Schlumberger/ IfS 7/18-28/93 Schlumberger ~ 7/18-28/93 Schlumberger st ~ * 7/24/93 Schlumberger 7/18/93 Schlumberger 12/11/93 Schlumberger 12/11/93 Schlumberger 12/12/93 LOG:Production Log FJ3S /TEMP /PRESS / Gr adio/HI~_ ~ Final Log: GYRO Directional Survey (GC_~T.) (~ Schlumberger 12/12/93 Schlumberger 1/7/94 Schlumberger Well Name P2-30 P2-30 P2-30 P242 P242 P242 P2-42 p~2P2-51 -51 Data Description FINAL LOG:~Compensated Neutron Log (Dual Porosity - CNT-G) Run # Date Run ~ 1/8/94 FINAL LOG: Dual Burst TDT-P (~ 1/8/94 "FINAL LOG: Perf Record 3 3/8 .... HJ II, 6 SPF"__(~qq% 1/17/94 "FINAL LOG:V~erf Record 270'3 3/8"" 6 SPF" /~IS Tape :c'~T,/C~~__~: 7500-10564 w / lis verification -~ LoO,Z~ FINAL LOG: ¥'~ement Bond Log (CBT-GR) FINAL LOG: Cement Evaluation Log (CE~-GR) Company Schlumberger Schlumberger Schlumberger 1/16-17/94 Schlumberger 1/9/94 Atlas V'Compensated Neutron Log (Dual Porosity- CNT-G) 1/15/94 Schlumberger qec - 5 '/Dual Burst TDT-P Log 1/15/94 Schlumberger ~g~--%vt~$Cc ~ ,, 1/11/94 Schlumberger 1/11/94 Schlumberger Please ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 PLEASE SIGN ONE COPY AND RETURN Transmittal Number: 703 Page: 2 TransmittaJ #367 (AOGCC) Page 2 I Well Tape/Diskette w/verification o~ '~ ~qZ.'5 '~'\°~"~ Run # Run Date Company PI-(tiST#1 C~Data in 2 ST Bit Runs (w/Orig. Well) 1 7/18/93_ Sdrlum~ Pl-16 Dual PropResis/Neu/Dens/GR -Depth Shifted°~ 4~ ~Ozo3/~9/.93%2":5~-Batmr~-~ghes~ I ' P1-21 Dual PropResis/Neu/Dens/GR-Depth Shifte~ 3z6 P2-12 Final MWD ~.~vct~k~- / - 8/31/93 Schlum~ P2-16 DIFL/GR, CN/ZDL/GR (LDW,G Tape & Di~'ket-te) - , 9/13/93 Atlas P2-16 Final MWD z~c~t~ +&~s~- t. OH' ~ 5:/zq 7~50-10S~_O 9/11/93 Schlum~ 0~ DZFL/CN/ZDL/GR (LDWG Ta~e & Disk~tte) ,Lt5 - 9/27/93 Atlas k'~ 5%Z, u~5-'~ zfl8' - 9/26/93 Schlumh~ Final MWD ~-t~ P2-46 P2-46 Please sign and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Transmittal #367 PLEASE SIGN ONE COPY AND RETURN Date: Subject: From: ARCO Alaska, Inc. Lisburne/Point Mclntyre Engineering December 2, 1993 Transmittal #367 ARCO Alaska Inc. To: Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 The following Point Mclntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Well Log 1 blueline 1 sepia I~LO- l~7~L~ 5" P1-01 Perforation Record 2-1/8" BH ENERJET Run # Run Date Company <qS~.~'~ P1-05 -'Static Pressure Survey/PRESS/TEMP/GR/CCL) fl%/'I21~~ LWD Very Enhanced Resistivity CDR~sqq' °t'lS'crn:*s'' ~~v'LWD Tree Vertical Depth CD - ~ 11/3-4/93 SddumNv3er iz,~00 93 Sdtlum~ 7/18-28/93 Sd-dum~ 11/26/93 Sddum~ 11/29/93 Schlum~ 11/07/93 S&lum~ ~0/24/93 Sddum~ ~0/24/93 ~0/24/93 Smtum~ lPl-17 0 .?~P1-17 ~Pl-17 ~-/'r~P2'16 ~ tP2-16 vl'~erforation Record 33/8" HSD -4lB -"Perforation Record 33/8" HSD-4lB v'Data Frac Log 'qToo-'tbZSOj ¢Cement Evaluation Log (CET-GR) ~2ement Bond Log (CBT-GR) 3~oo-10q0o 5,' v'Cement Evaluation Log (CET-GR) q ~~P2-46 P2-46 _ IP2-57 i t'?~P2.57 IP2-60 q ~~L~P2-60 [P2-60 ) -'Cement Bond Log (CBT-GR) ,tTz-qz%8, s" 1 10/24/% /-~xatic Botto~itl,uleSta-v-,y (FRESS/TEivlF/G-R) ~o-~o i, 51/26/93 ,'Compensated Neutron Log (2.5" CNT-D/CH) q*co"iq~e'l~)14/93 k-v~Perforation Record (3-2/8" Gun 4lB H~) 1 11/14./.93 b-~l~ooO~ 5" ¢Static Pressure Survey fPRESS/TElVIlV/GR/CCL)I 7'%[1 11/18/93 ¢Per£oration Record 33/8'' -4lB ~ I~vq%e; lze~¢~ 5"1 11/14/93 PLEASE SIGN ONE COPY AND RETURN Transmittal ¢~361 (AOGCC) Page 2 Log Well Title 1 sepia P1-21 ./Integrated Formation Log -MD P1-21 V' Integrated Formation Log-TVD P1-21 JEngineering Parameters-MD P1-21 /Pressure Data Log-MD P2-06 v~Z-Demsilog/Cmpnstd NEUTRON/GR/Ca~per 1 P2-06 ,al'Dual Laterolog/Gamma Ray/SP 1 P2-06 ,/Sub-Sea Vertical Depth (Single Shot Data) 1 P2-06 ,/'Borehole Profile I P2-16 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caiiper 1 P2-16 v/Dual Induction Focused Log/Gamma Ray 1 P2-16 ,/Sub-Sea Vertical Depth (Multi Shot Data) 1 P2-16 7'Borehole Profile 1 P2-46 P2-46 P2-46 P2-46 ,/Z-Densilog/Cmpnstd NEU~ON/GR/Caliper 1 ,/'Dual Induction Focused Log/Gamma Ray 1 ,/Sub-Sea Vertical Depth (Directional Drlg Data) 1 dBorehole Profile I Run # Run Date - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 8/17/93 8/17/93 8/17/93 8/17/93 9/13/93 9113193 9113193 9113/93 9/27/93 9127193 9/27/93 9127/93 Company Erdog Exlog Exlog Exlog Atlas Arias Atlas Arias Arias Atlas Atlas Atlas Arias Atlas Atlas Atlas Please and return to: Laura S. Lahrson, ATO409 ARCO Alaska, Inc. 'P.O, BOX 100360 Anchorage, Alaska 99510-0360 Transmittal #361 RECEIVED NOV 79 1995 ~aska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN ~ ransmittal ¢¢359 (AOGCC) Page 2 Log Well Tide I blue line Run # Run Date Company 4/30-5/5/93 Exlog ~c~--IL%%5'~ ;z" ..SA°9 P1-21 Integrated Formation Log ~ P1-21 Integrated Formation Log -~X~/ '- 4/30-5/5/93 Exlog Coco- P1-21 Engineering Parameters ~ - 4/30-5/5/93 Extog ~"; P1-21 Pressure Data Log -MDw'' - 4/30-5/5/93 Exlog ~J' ~zz:~ -- ? 'P2-06 Z-Densilog/Cmpnstd NEUTRON/GR/Caliper-'e ~S"> 11~,o0- 8/17/93 Atlas P2-06 Dual Laterolog/Gamma Ray/SP ' 1 8/17/93 Atlas ,,~-S'~ P2-06 Sub-Sea Vertical Depth (Single Shot Data)~,.1 8/17/93 Atlas iP2-06 Borehole Profile 1 8/17/93 Atlas ~--> ;el'' ~tq0e- ,itt-too-1~15~ 9/13/93 Atlas P2-16 Z-Densilog/Cmpnstd NEUTRON/GR/C~Per/7~ lvoTo-. P2-16 Dual Induction Focused Log/Gamma Ray 1 9/13/93 Atlas ,-~ P2-16 Sub-Sea Vertical Depth (Multi Shot Data) 1 9/13/93 Arias P2-16 Borehole Profile 1 9/13/93 Atlas ",,'> ~, \oo'"?O-.'-l~t~ P2-46 Z-Densilog/Cmpnstd NEUTRON / GR/Caliper /P2-46 Dual Induction Focused Log/Gamma Ray ~P2-46 Sub-Sea Vertical Depth (Directional Drlg Data) IP2-46 Borehole Profile 1 9/27/93 Atlas Diskette/Tape (w/verification listing) Well Title 9/27/93 Arias 9/27/93 Atlas Se5"~ 1 9/27/93 Atlas -'/% b-.--/~%%o Run # Run Date Company P1-04 P1-05 P1-05 P1-05 P1-08 P1-08 IPl-13 Pl-13 IPI-17 IP2-06 P2-06 P2-06 GCT diskette-Complete Calc. v' 1 7/28/93 Schlumberger GCT diskette-Complete Calc.~/' 1 8/12/93 Schlumberger CaN/CDR MAD Data in 1 Bit Run (O.....~ Edit)~l'~l l;'37~P0~/¢3~Schlumberger CDN/CDR in 3 Bit Runs (O._~ Edit)v' qclSq--tt ~r-~ ~5519 Final ~D w/list~g ~ ~ - CDR/GR'Offiy ~ 5 Bit R~s (OH Effit) ¢~513/~w'i~° Du~ ~op ReSis/Densi~/Neu~on/GRw/Hs~g 5-7 Fin~ ~D w/~sfin~~ - F~ ~D w/Listing ~ ~ / - CaN/CDR ~ 3 Bit R~s (O~ Effit)~k/~-~1~7&,5 1 DLL/~/ZDL/GR ~ LDWG Fomat w/Ust~g 1 6/27/93 7/13/93 7/24/93 6/6/93 6/07/93 4/16/93 4/16/93 8/17/93 8/17/93 8/17/93 Schlumberger Schlumberger Schlumberger Baker Hughes Baker Hughes Baker Hughes Baker Hughes Baker Hughes Schlumberger Atlas PLEASE SIGN ONE COPY AND RETURN Transmittal #~59 (AOGCC) Page 3 Report Well c1~-'¢3 P1-04 q%-8-/ P1-05 P1-08 ~/~,~Ttt Pl-13 q5-'51 Pl-17 Title Sub-Surface Directional Survey (2 copies)v/ Sub-Surface Directional Survey (2 copies) Final Well Report Final Well Report ~" Final Well Report," Final Well Report,,, Date 7/28/93 8/12/93 7/19-8/1/93 6/1-11/93 4/12-16/93 4/30-5/5/93 Company Schlumberger Schlumberger Exlog Exlog Exlog Exlog Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 · Anchorage, Alaska 99510-0360 Please note: The Exlog blueline logs are located within the Final Well Report binders. Transmittal #359 PLEASE SIGN ONE COPY AND RETURN Transmittal #361 (AOGCC) Page 2 Log ~ell TiQe 1 sepia P1-21 ,./Integrated Formation Log-MD P1-21 V' Integrated Formation Log -TVD P1-21 v/Engineering Parameters-MD P1-21 /Pressure Data Log-MD P2-06 v~Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-06 ,/'Dual Laterolog/Gamma Ray/SP 1 P2-06 ,/Sub-Sea Vertical Depth (Single Shot Data) 1 P2-06 v/Borehole Profile 1 P2-16 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-16 v'Dual Induction Focused Log/Gamma Ray 1 P2-16 v/Sub-Sea Vertical Depth (Multi Shot Data) 1 P2-16 ,/Borehole Profile I P2-46 d'Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-46 ~'Dual Induction Focused Log/Gamma Ray 1 P2-46 ./Sub-Sea Vertical Depth (Directional Drlg Data) 1 P2-46 ./q3orehole Profile I Run # Run Date - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 8/17/93 8/17/93 8/17/93 8/17/93 9/13/93 9/13/93 9/13/93 9/13/93 9/27/93 9/27/93 9/27/93 9/27/93 Company Exlog Exlog Exlog Exlog Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Please sign .... and return to' Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Transmittal #361 RECEIVED NOV 19 1993 A/aska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Date: Subject: From: October 13, 1993 Transmittal #359 ARCO Alaska Inc. ARCO Alaska, Inc. ...:sburne/Point McIntyre Engineer. To.' Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well Title ' P1-04 Completion Record, Perforation HSD 6 sfp 3%8" ~ ~o?o-1~o5 ~' ,, P1-05 Perforating Record 3%" HSD 4lB HI II RDX 5 , P1-05 P1-05 P1-05 P1-05 Pl-08 Pl-08 Pl-08 Pl-08 Perforating Record 3%" I-LSD 4lB I-ti II RDX- 5" Perforating Record 3%" HSD 4lB I-ti II RDX- 5", Perforating-Record 3%8".HSD 4lB I-ti II RDX" 5"~ Perforating Record 33/8'' HSD 4lB I-II II RDX · -- Integrated Formation Log -(~' ~oqoo- toolbox" Integrated Formation Log~--D C0s%~---~??z', :z" - Engineering Parameters ~.~ Z5 t. moo- t'co,..[o' - Pressure Data Log-MD 1"~ o52z> - fl?~' - Run # 'Run Date Company I 8/19/93 Schlumberger. 1iz~w'~ 8/23/93 Schlumberger 1 ~ '~ 8/30/93 Schlumberger l~t,,ti~8/31/93 Schlumberger 1.~,~9/01/93 Schlumberger 1 ,,.~"9/02/93 Schlumberger 7/1%24/93 7/ 9-24/93 711%24193 711%24/93 Exlog Exlog l ~ Exlog Exlog Integrated Formation Log ~.2",, ~go-to~m0' _ Integrated Formation Log ~~)2', ~'~0~%?~ Engineering Parameters ~ ~" ~ ~ 70 ~ l eqco' Pressure Data Log-MD !~ ~lz5-~?~' - 7/25-31/93 7/25-31/93 7/25-31/93 7/25-31/93 Exlog Exlog Exlog Exlog Pl-13 Pl-13 Pl-13 Pl-13 Integrated Formation _Log - Integrated Formation Log ~ ,b ~o- 77~;5 Engineering Parameters -cMD2'~, (oqcO- il coo Pressure Data Log -MD ~" co~o -- ~,v ~ - 6/1-11/93 6/1-11/93 6/1-11/93 6/1-11/93 Exlog Exlog Exlog Exlog Pl-17 Pl-17 Pl-17 Pl-17 Integrated Formation Log Integrated Formation Log Engineering Parameters Pressure Data Log-MD 4112-16/93 4112-16/93 4/12-16193 4112-16193 Exlog Exlog Exlog Exlog PLEASE SIGN ONE COPY AND RETURN Date: Subject: ~rom: ARCO Alaska, Inc. .~burne/Point McIntyre Engineerh,§ November 17, 1993 Transmittal #361 ARCO Alaska Inc. To: Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 Enclosed are sepias for the following Point Mclntyre logs. These sepias were erroneously omitted from Transmittal #359, sent 10/13/93. This information is confidential and your cooperation in maintaining confidentiality is appredated. Log Well Title Run # Run Date Company 1 sepia ° P1-04 Completion Record, Perforation HSD 6 sfp 33/8" 1 8/19/93 Schlumberger t P1-05 /Perforating Record 3%" HSD 4lB HI II RDX I 8/23/93 Schlumberger P1-05 ,/'Perforating Record 3%8" HSD 4lB HI H RDX 1 8/30/93. Schlumberger P1-05 v'Perforating .Record 3%a" HSD 41B HI tl RDX I 8/31/93 Schiumberger 1-05 x/Perforating Record 33/8'' HSD 41B HI 17 RDX I 9/01/93 Schlumberger 1-05 v,Perforating Record 3%8" HSD 41B HI 17 RDX I 9/02/93 Schlumberger P1-08 ,/l. ntegrated Formation Log-MD - 7/19-24/93 Exlog P1-08 ,/'Integrated Formation Log-TVD - 7/19-24/93 Exlog P1-08 v/En~neering Parameters -MD - 7/19-24/93 Exlog P1-08 ,,'Pressure Data Log-MD - 7/19-24/93 Exlog 1,/'FI-(BSTI' Integrated Formation Log -MD ~'J~ [x/FI-OSST1 Integrated Formation Log-TVD ~ x/PI-GSST1 Engineering Parameters -MD I v4214~ST1 Pressure Data Log-MD · 7/25-31/93 · Exlog 7/25-31/93 Exlog 7/25-31/93 Exlog 7/25-31/93 Exlog P1-13 ,/'Integrated Formation Log-MD Pl-13 v' Integrated Formation Log -TVD tP1-13 ,/Engineering Parameters -MD P1-13 '/'Pressure Data Log-MD' - 6/1-11/93 Exlog - 6/1-11/93 Exlog - 6/1-11/93 Exlog - 6/1-11/93 Exiog Pl-17 ,/'Integrated Formation Log-MD P1-17 v/Integrated Formation Log-TVD P1-17 v/ Engineering Parameters -MD P1-17 v/Pressure Data Log-MD - 4/12-16/93 Exlog - 4/12-16/93 Exlog - 4/12-16/93 Exlog - 4/12-16/93 Exlog PLEASE SIGN ONE COPY AND RETURN Al~ska Oil Gas Coas~r,,ation Commission JUU i Horcupine Drive Anchorage, Alaska §§5t]1-3192 The following data is hereby acknowledged as being received' I I ! Dated: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS I-I SI.ISPEi',~_D [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit(~Number_ (~,..,. 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029. 4. Location of well at surface 9. Unit or Lease Name ,~-.~ 1379'NS!~ 923' WEL, SEC. 16, T12N, R14E Point Mclntyre At Top Producing Interval ! ~i~,~.'r~ ! .J! ~'~,~D ~ P1-21 2103'NSL, 46'EWL, SEC. 10, T12N, R14E i.~zZZZ/2_E~ ! 11. Field and Pool 2383'NS1~ 114'EWL, SEC. 10, T12N, R14E ~ ................. ~ " 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 50' I ADL 12. Date Spudded 13. Da~e T.D. Reached 14. Date Comp., Susp. o~ Aband. 115. Water Depth, if offshore 116. No. ol Completions 4/24/93 5/5/93 5/17/93I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set ~21. Thickness of Permafrost 11525' MD/9202' TVD 11432' MD/9126' TVD YES [] t,D []! 2224' feet MD/ 1750'(Approx.) 22. Type Electric or Other Logs Run TEMP/CHT/CNI_/GR/Z-DEN/DLL 23. CASING, LINER AND CEMENTING ~ SETrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 26" 281 cu ft Arctic'set 10-3/4" 45.5/1 J-55 40' 4020' 13-1/2" 2387 cu ft PF "E"/402 ~u ft "G" 7-5/8" 29. 7# NT95HS 40' 11513' 9-7/8" 667 cuft C/ass "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 3-3/8" 4 s__pf._ 4-1/2" 10954' 10874' MD TVD 11102'-11112' 8808'-8816' 11129'-11146' 8830'-8844' 26. ACID, FRACTURE, CEMENT SQUEEZF~ ETC. 11169'-11229' 8862'-8910' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAl. USED 11249'-11339' 8926'-9000' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Not on production I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ot oil, gas or water. Submit core chips. RE E VE, Alaska Oil & Gas Cons. Corr~t'nissio~'" Anchorage Form 10-407 Submil in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOL~ MARKERS FuRMATION TESTS NAME Include inlerval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Kalubik 10960' 8694' Kuparuk 11031' 8751' U3 11248' 8925' L3B 11475' 9111' Al~$k~ Oil & '~ oor s. Cormnissiorl Anchorage 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/(~' ~ - -~/~. '~) L"" TitleDrillinQ_rn_clino@rSuD~cVl$or Dateq'-~' ~'~) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: P1-21 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/22/93 10:00 SPUD: 04/24/93 11:00 RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 04/23/93 (1) TD: 110'( 0) 04/24/93 ( 2) TD: 110'( 0) R/U. MW: 8.5 VIS: 0 MOVE RIG. RIB ACCEPTED @ 22:00 HRS, 4/22/93. N/U DIVERTER. MIX SPUD MUD. WORK ON TOP DRIVE. REPLACE TOP DRIVE. MW: 8.7 VIS:ll0 04/25/93 (3) TD: 1543' (1433) 04/26/93 (4) TD: 4035'(2492) 04/27/93 ( 5) TD: 4035' ( 0) 04/28/93 ( 6) TD: 5350' (1315) 04/29/93 (7) TD: 6936' (1586) 04/30/93 (8) TD: 7660' ( 724) 05/01/93 (9) TD: 8035' ( 375) 05/02/93 (10) TD: 9530' (1495) DRLG. MW: 9.0 VIS:180 REPAIR TOP DRIVE. TEST DIVERTER. RIH W/ BHA. SPUD WELL @ 11:00 HRS, 4/24/93. DRLG F/ 82'-1543' SURVEY. MW: 9.4 VIS: 94 DRLG F/ 1543'-2853'. CBU. SHORT TRIP 10 STDS. DRLG F/ 2853'-4035' CBU. SHORT TRIP TO HWDP. CBU. TEST BOPE. MW: 9.4 VIS: 56 CIRC. POOH. L/D BHA. RIH W/ 10-3/4" CSG. CIRC. PUMP 75 BBLS WATER, 425 BBLS LEAD CMT, 72 BBLS TAIL CMT. DISP W/ MUD. BUMP PLUG. N/D DIVERTER. N/U BOPE. TEST BOPE. DRLG. MW: 9.0 VIS: 57 TEST BOPE. RIH W/ BHA. TET CSG. OK. DRLG FC, CMT TO 3989' CIRC. DRLG FS, 10' NEW HOLE. CIRC. LOT (13.3 PPG EMW) . DISP TO KCL. DRLG F/ 4045'-5101' CBU. SHORT TRIP TO SHOE. DRLG TO 5350' POOH. MW: 9.1 VIS: 56 DRLG F/ 5350'-6132' CBU. SHORT TRIP TO 4020' DRLG F/ 6132'-6938' POOH FOR WASHOUT. DRLG. MW: 9.3 VIS: 54 POOH FOR WASHOUT. FOUND IN BIT. CHANGE BIT. RIH. REAM TO BTM. DRLG F/ 6938'-7660'. RIH. MW: 9.4 VIS: 49 DRLG F/ 7660'-7932'. CIRC. SHORT TRIP 11 STDS. DRLG F/ 7932'-8035'. CBU. POOH. CHANGE BHA. RIH. DRLG. MW: 9.6 VIS: 55 RIH. LOG F/ 7980'-8035' DRLG F/ 8035'-9530' ,Alaska 0il & Gas Cons. Commission A n q ~ i-~ I"~ ~ ~o WELL : P1-21 OPERATION: RIG : POOL 7 PAGE: 2 05/03/93 (11) TD: 9880' ( 350) 05/04/93 (12) TD:ll003' ( 1123) 05/05/93 (13) TD:l1260' ( 257) 05/06/93 (14) TD:11525' ( 265) 05/07/93 (15) TD:11525' ( 0) 05/08/93 (16) TD:11525 PB: 0 DRLG. MW: 9.8 VIS: 48 DRLG F/ 9530'-9616'. CBU. PUMP OUT TO 6548' CIRC. POOH. CHANGE BHA. RIH. REAM 90' TO BTM. DRLG F/ 9530'-9880'. POOH. MW: 9.8 VIS: 49 DRLG F/ 9880'-10629' CIRC. SHORT TRIP 11 STDS. DRLG F/ 10629'-11003'. CBU. POOH. DRLG. MW:10.0 VIS: 51 POOH. CHANGE BHA. TEST BOPE. RIH. MAD RUN 40' TO BTM. DRLG F/ 11003'-11260'. WIPER TRIP. MW:10.0 VIS: 53 DRLG F/ 11260'-11525' TD WELL @ 14:00 HRS, 5/5/93. CIRC. POOH. R/U ATLAS. LOG RUN: TEMP/CHT/CNL/GR/ZDEN/DLL. NO GO PAST 10985' R/D ATLAS. RIH W/ BHA. CIRC. MW:10.0 VIS: 60 RIH. REAM F/ 10905'-11525' CIRC. POOH 8 STDS. RIH 3 STDS. POOH. R/U ATLAS. LOG RUN: GR/TEMP/CN/ZDL/DLL. NO GO PAST 10664'. POOH. R/D ATLAS. RIH. REAM F/ 10664'-11525' CIRC. RUN CSG. MW:10.2 CIRC. SHORT TRIP 15 STDS. CIRC. SHORT TRIP. CIRC. POOH. L/D BHA. TEST BOPE. RIH W/ 7-5/8" CSG. KCl 05/09/93 (17) TD:11525 PB:11435 05/10/93 (18) TD:11525 PB:11435 05/11/93 (19) TD:11525 PB:11435 R/U ATLAS. MW: 8.5 Seawater RIH W/ CSG. CBU. RIH W/ CSG TO 8000' CBU. RIH W/ CSG. WORK TO BTM. CIRC. PUMP PREFLUSH, 12~ BBLS CMT. DISP W/ SEAWATER. BUMP PLU GW/ 2500 PSI. INSTALL PACKOFF. TEST SAME. INJECT 150 BBLS MUD DN ANNULUS. F/P W/ 120 BBLS 50/50. R/U ATLAS. TEST TBG. MW: 8.5 Seawater RIH W/ GR/JB. PBTD @ 11435' TEST CSG. OK. TEST BOPE. RIH W/ 4-1/2" TBG, PKR, SSSV. M/U HGR. LAND TBG. L/D LAND JT. N/D BOPE. N/U TREE. TEST TREE. OK. PUMP 225 BBLS DIESEL DN TBG. SET PKR. TEST TBG, PKR. RIG RELEASED. MW: 8.5 Seawater TEST TBG. TEST ANNULUS. OK. SET BPV. RIG RELEASED @ 09:00 HRS, 5/10/93. SIGNATURE: (drilling superintendent ) DATE: SUB - SURFA CE DIRECTIONAL SURVEY r-~ UIDANCE [~ ONTINUOUS [-~ OOL IC OFILMED Company 'Well Name Field/Location ARCO ALASKA, INC. P1-21 (1379' FSL~ 923' FELt SEC 16~ T12N~ R14E) POINT MCINTYRE, NORTH SLOPE, ALASKA Job Reference No. 93234 Loqqed By: HCCROSSAN Date 12-NAY-93 Computed By: · SINES . SCHLUMBERGER * QCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. PI - 21 POINT MCINTYRE NORTH SLOPE, ALASKA SURVEY DATE' 12-MAY-1993 ENGINEER- J. MCCROSSAN METHODS OF COMPUTATION TOOL LOCATION: MINIk~J~ CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 9 DEG 18 MIN EAST COMPUTATION DATE' 11-JUN-93 PAGE I ARCO ALASKA, INC. Pi - 21 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 12-MAY-1993 KELLY BUSHING ELEVATION' 50.00 ET ENGINEER' J. MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIM DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 oo 600 O0 700 O0 800 O0 900 O0 0 O0 lO0 O5 2OO O5 3OO O5 400 05 5OO O5 600 05 700 05 800 05 9OO O5 -50 O0 5O O5 150 05 25O O5 35O O5 450 05 55O O5 65O O5 750 05 850 05 0 0 N 0 0 E 0 5 S 4O 59 E 0 5 N 48 12 E 0 10 S 27 53 E 0 0 N 21 55 W 0 5 S 1034 W 0 10 S 16 56 W 0 14 S 6 42 W 0 13 S 744 E 0 23 N 38 35 E 0 O0 0 01 0 02 -O 01 -0 20 -0 35 -0 62 '-1 05 -1 51 -1 67 0 O0 0 O0 0 O0 0 39 0 09 0 14 0 33 0 38 0 85 1 80' 0 O0 N 0 O0 S 0 O0 S 0 06 S 0 24 S 0 39 S 0 67 S I 10 S I 58S 1 77 S 0 O0 E 0 06 E 0 15 E 0 32 E 0 24 E 0 26 E 0 26 E 026E 0 29 E 0 46 E 0 O0 N 0 0 E 06 S 88 32 E 15 S 89 35 E 32 S 79 4 E 34 S 45 3 E 47 S 33 33 E 72 S 21 7 E 13 S 13 27 E 61 S 10 18 E 83 S 14 29 E 1000 O0 1000 02 lioO 1200 1300 1400 1500 1600 1700 1800 1900 oo 1099 O0 1199 O0 1298 O0 1396 O0 1493 O0 1591 O0 1687 O0 1783 O0 1877 950 02 84 1049 29 1149 03 1248 13 1346 84 1443 11 1541 70 1637 54 1733 67 1827 1 59 N 29 7 E 84 4 43 N 32 40 E 29 7 32 N 34 14 E 03 10 24 N 32 16 E 13 11 47 N 28 29 E 84 12 46 N 19 34 E 11 14 16 N 17 18 E 70 15 39 N 17 36 E 54 17 48 N 14 47 E 67 21 51 N 12 17 E 0.'10 5.61 15 O1 29 47 47 47 68 08 90 97 116 61 144 90 178 48 1 98 3 58 2 43 2 11 0 84 1 40 1 54 1 43 3 59 5 O1 0 13 S 4 96 N 13 51N 26 77 N 43 38 N 62 88 N 84 89 N 109 59 N 136 95 N 169 69 N 1 45 E 4 43 E 10 35 E 18 88 E 28 81E 37 32 E 44 53 E 52 60 68 1 46 S 84 42 E 6 17 32 52 73 95 30 E 121 33 E 149 23 E 182 65 N 41 45 E 02 N 37 27 E 76 N 35 12 E 08 N 33 35 E 12 N 30 41E 86 N 27 41E 44 N 25 31E 65 N 23 46 E 89 N 21 54 E 2000 O0 1968 92 1918 92 25 49 2100 2200 2300 2400 250O 2600 2700 2800 2900 N 8 11 E O0 2058 O0 2149 O0 2239 O0 2327 O0 2414 O0 2499 O0 2581 00'2662 O0 2741 93 2008 32 2099 O1 2189 52 2277 86 2364 30 2449 95 2531 71 2612 42 2691 93 25 36 N 9 37 E 32 25 25 N 9 47 E O1 27 8 N 5 49 E 52 28 12 N 5 34 E 86 3O 40 N 4 24 E 30 33 34 N 3 49 E 95 34 56 N 4 52 E 71 37 28 N 5 17 E 42 38 41 N 5 26 E 219 33 262 89 305 66 349 85 396 28 444 85 498 13 554 22 613 02 674 55 1 O1 1 06 1 51 1 54 1 O7 4 95 1 61 1 69 1 74 1 61 209 94 N 253 295 338 385 433 487 543 602 663 75 18 E 222 99 N 19 42 E O1N 81 13 N 89 97 N 94 28 N 99 75 N 103 18 N 107 30 N 111 02 N 117 44 N 122 71E 265 20 E 308 93 E 352 43 E 397 96 E 446 44 E 498 75 E 554 O1E 613 75 E 674 87 N 17 54 E 31 N 16 49 E O1 N 15 39 E 90 N 14 28 E 03 N 13 29 E 88 N 12 26 E 67 N 11 37 E 29 N 11 0 E 7O N 10 29 E 3000 O0. 2818 34 2768 34 40 41 3100 O0 2893 06 2843 06 42 40 3200 O0 2965 84 2915 84 43 56 3300 O0 3036 52 2986 52 45 59 3400 O0 .3105 77 3055 77 45 47 3500 O0 3176 55 3126 55 44 30 3600.00 3247 72 3197 72 44 48 3700.00 3319.05 3269.05 43 58 3800.00 3391.27 3341.27 43 44 3900.00 3463.56 3413.56 43 41 N 5 33 E 738.31 N 4 32 E 804.56 N 5 29 E 872.94 N 6 20 E 943.56 N 5 7 E 1015.55 N 5 32 E 1086.02 N 5 48 E 1156.13 N 5 55 E 1226.08 N 6 12 E 1295.15 N 6 33 E 1364.14 1 46 1 58 1 91 1 40 2 36 0 42 0 13 1 25 0 30 0 56 727 03 N 128 94 E 738 37 N 10 3 E 793 861 931 1003 1074 1143 1213 1282 1351 22 N 134 55 N 140 88 N 148 66 N 155 O0 N 161 90 N 168 62 N 175 41N 183 07 N 190 68 E 804 57 E 872 08 E 943 22 E 1015 72 E 1086 70 E 1156 81E 1226 12 E 1295 79 E 1364 57 N 9 38 E 94 N 9 16 E 57 N 9 2 E 59 N 8 47 E 11 N 8 34 E 27 N 8 23 E 29 N 8 15 E 42 N 8 8 E 47 N 8 2 E COMPUTATION DATE' 11-JUN-93 PAGE 2 ARCO ALASKA, INC. Pi - 21 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 12-MAY-1993 KELLY BUSHING ELEVATION' 50.00 FT ENGINEER' J'. MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH ~ST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3535.75 3485 75 43 41 N 6 48 E 1433 27 4100 420O 4300 4.400 4500 4600 4700 4800 4900 O0 3608 20 3558 O0 3680 O0 3751 O0 3821 O0 3892 O0 3964 O0 4037 O0 4111 oo 4185 08 3630 11 3701 66 3771 66 3842 7O 3914 95 3987 51 4061 16 4135 20 43 45 N 6 50 E 1502 08 44 22 N 7 9 E 1571 11 45 6 N 7 37 E 1641 66 44 59 N 7 44 E 1712 66 44 24 N 7 48 E 1783 70 43 15 N '8 5 E 1852 95 42 46 N 8 17 E 1920 51 42 27 N 8 8 E 1988 16 42 42 N 8 2 E 2055 0 86 1419 81 N 198 81 E 1433 66 N 7 58 E 14 0 6O 0 95 0 8O 0 18 0 52 2 58 0 32 0 94 0 68 1488 69 1557 76 1627 27 1697 74 1767 27 1835 15 1903 56 1970 80 2037 25 N 2O7 25 N 215 O5 N 224 29 N 233 O6 N 243 76 N 253 13 N 262 18 N 272 14 N 281 Ol E 1502 47 E 1572 51E 1642 ~9 E 1713 5O E 1783 03 E 1853 81E 1921 50 E 1988 99 E 2O56 57 N 7 55 E 09 N 7 53 E 47 N 7 51 E 34 N 7 51 E 76 N 7 51 E 11 N 7 51 E 19 N 7 52 E 93 N 7 52 E 57 N 7 53 E 5000 O0 4258 34 4208 34 43 7 N 7 55 E 2124 07 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4331 O0 4403 O0 4476 O0 4549 O0 4623 O0 4698 O0 4773 O0 4849 O0 4926 23 4281 94 4353 57 4426 91 4499 88 4573 51 4648 83 4723 78 4799 18 4876 23 43 19 N 7 44 E 2192 94 43 26 N 7 27 E 2261 57 43 8 N 7 20 E 2329 91 42 51 N 7 25 E 2397 88 42 1 N 7 42 E 2465 51 41 23 N 7 41 E 2531 83 40 52 N 7 41 E 2597 78 40 25 N 7 34 E 2662 18 39 53 N 7 26 E 2726 51 13 84 77 04 58 32 34 84 0 24 2104 64 N 291 45 E 2124 72 N 7 53 E 14 2172 43 224O 58 2308 51 2376 41 2442 64 2508 O4 2573 03 2638 29 2702 47 N 300 52 N 309 69 N 318 10 N 327 81N 336 77 N 345 95 N 353 42 N 362 40 N 371 75 E 2193 82 E 2261 62 E 2330 37 E 2398 26 E 2465 18 E 2532 98 E 2598 64 E 2663 O6 E 2727 19 N 7 53 E 83 N 7 52 E 57 N 7 51 E 55 N 7 51 E 85 N 7 5O E 41 N 7 5O E 17 N 7 5O E 23 N 7 50 E 75 N 7 49 E 6000 O0 5003 21 4953 21 39 24 N 7 10 E 2790 57 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5080 O0 5155 O0 5229 O0 5302 O0 5375 O0 5447 O0 5518 O0 5589 O0 5660 09 5030 64 5105 92 5179 80 5252 16 5325 07 5397 46 5468 34 5539 75 5610 09 40 12 N 7 14 E 2854 64 41 33 N 8 3 E 2919 92 42 37 N 8 13 E 2986 80 43 37 N 8 22 E 3055 16 43 50 N 8 29 E 3124 07 44 6 N 8 59 E 3193 46 44 51 N 9 28 E 3263 34 44 39 N 9 46 E 3334 47 95 89 34 37 85 87 41 75 44 11 N 9 57 E 3404.41 0 53 2765 65 N 379 15 E 2791.52 N 7 48 E O1 2829 09 N 387 84 2894 O1 N 395 34 2960 29 N 405 60 3028 04 N 415 56 3096 32 N 425 63 3165 02 N 435 06 3234.12 N 447 73 3303.67 N 458 81 3372.64 N 470 17 E 2855.46 N 7 48 E 88 E 2920.97 N 7 47 E 38 E 2987.92 N 7 48 E 27 E 3056~38 N 7 49 E 39 E 3125.40 N 7 49 E 87 E 3194.89 N 7 50 E 14 E 3264.88 N 7 52 E 94 E 3335.40 N 7 55 E 93 E 3405.36 N 7 57 E 7000 O0 5732.89 5582 89 43 43 N 9 59 E 3473 66 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5805.17 5755 O0 5877.53 5827 O0 5949.61 5899 O0 6021.44 5971 O0 6093.46 6043 O0 6165.93 6115 O0 6240.37 6190 O0 6315.78 6265 O0 6391.58 6341 17 43 39 N 10 10 E 3542 53 43 39 N 10 18 E 3611 61 44 4 N 10 15 E 3681 44 44 3 N 9 55 E 3750 46 43 52 N 9 21 E 3820 93 42 51 N 7 43 E 3888 37 41 11 N 6 52 E 3955 78 40 56 N 6 44 E 4021 58 40 31 N 6 44 E 4086 76 77 O8 65 O2 92 63 25 41 0 56 3440.84 N 482.93 E 3474 57 N 7 59 E 29 3508.89 N 494.97 E 3543 47 3576.81 N 507.26 E 3612 41 3645.01 N 519.65 E 3681 12 3713.52 N 531.78 E 3751 63 3781.91 N 543.47 E 3820 56 3850.01 N 553.89 E 3889 87 3916.26 N 562.17 E 3956 O1 3981.48 N 569.91 E 4022 49 4046.26 N 577.56 E 4087 63 N 8 2 E 60 N 8 4 E 87 N 8 7 E 40 N 8 9 E 76 N 8 11 E 65 N 8 11 E 40 N 8 10 E 06 N 8 9 E 27 N 8 7 E COMPUTATZON DATE: 11-JUN-93 PAGE 3 ARCO ALASKA, INC. P1 , 21 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 12-MAY-1993 KELLY BUSHING ELEVATION: 50.00 FT ENGINEER: J. MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDZNATES HORZZ. DEPARTURE MEASURED VERTZCAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 6468 24 6418 24 39 25 N 7 22 E 4150 56 8100 82O0 8300 8400 8500 8600 8700 8800 8900 O0 6545 O0 6623 O0 6701 O0 6780 O0 6860 O0 6940 O0 7020 O0 7100 O0 7180 66 6495 46 6573 8O 6651 83 6730 26 6810 23 6890 73 6970 42 7050 42 7130 66 39 2 N 7 33 E 4213 46 38 42 N 7 48 E 4276 80 38 3 N 7 37 E 4338 83 37 29 N 7 38 E 4400 26 37 15 N 7 22 E 4460 23 36 32 N 7 34 E '4520 73 36 37 N 8 31 E 4580 42 37 20 N 9 47 E 4640 42 36 20 N 11 9 E 4700 0 75 4110 O0 N 585 27 E 4151 47 N 8 6 E 83 0 63 0 75 0 O0 0 72 0 73 0 04 44 1 43 44 4172 48 4235 80 4296 49 4357 30 4417 68 4477 74 4535 15 4595 48 4654 75 N 593 02 N 601 60 N 610 33 N 618 56 N 626 10 N 634 86 N 642 48 N 652 49 N 662 59 E 4214 95 E 4277 30 E 4339 46 E 440,1 39 E 4461 14 E 4521 33 E 4581 O1E 4641 88 E 4701 76 N 8 6 E 59 N 8 5 E 73 N 8 5 E O0 N 8 5 E 75 N 8 4 E 79 N 8 4 E 11 N 8 4 E 5O N 8 5 E 45 N 8 6 E 9000 O0 7260 98 7210 98 37 2 N 12 46 E 4759.'61 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7339 O0 7415 O0 7490 O0 7562 O0 7634 O0 7708 O0 7782 O0 7856 O0 7931 29 7289 28 7365 53 7440 69 7512 76 7584 02 7658 05 7732 49 7806 35 7881 29 39 52 N 13 36 E 4821.62 28 40 36 N 14 33 E 4886 41 53 42 26 N 14 10 E 4951 97 69 44 21 N 12 44 E 5021 02 76 43 22 N 12 47 E 5090 22 02 42 31 N 12 12 E 5158 18 05 42 6 N 12 18 E 5225 32 49 41 40 N 12 6 E 5292 O1 35 41 26 N 12 9 E 5358 23 2 79 4712 44 N '675 20 E 4760.56 N 8 9 E 67 4772 15 4836 91 4899 68 4967 06 5034 91 5101 66 5166 67 5232 24 5296 95 N 689 03 N 705 74 N .721 10 N 737 71N 753 18 N 767 87 N 781 15 N 796 97 N 809 44 E 4822.48 N 8 13 E 15 E 4887.17 N 8 18 E 74 E 4952 61 N 8 23 E 70 E 5021 58 N 8 27 E O0 E 5090 71 N 8 30 E 64 E 5158 61 N 8 33 E 92 E 5225 70 N 8 36 E O0 E 5292 35 N 8 39 E 90 E 5358 53 N 8 42 E 10000 O0 8006 39 7956 39 41 18 N 12 17 E 5424 24 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 8081 O0 8156 O0 8232 O0 8308 O0 8385 O0 8462 O0 8539 O0 8617 O0 '8696 63 8031 92 8106 63 8182 88 8258 45 8335 29 8412 57 8489 46 8567 16 8646 63 41 !1 N 12 35 E 5490 92 41 3 N 12 50 E 5555 63 40 34 N 12 51 E 5620 88 40 5 N 12 43 E 5685 45 39 59 N 12 51 E 5749 29 39 35 N 13 9 E 5813 57 39 9 N 12 51 E 5876 46 38 30 N 12 31 E 5939 16 37 33 N 12 20 E 6001 02 72 93 50 70 57 89 50 10 0 28 5361 57 N 823 88 E 5424.50 N 8 44 E 23 5425 14 5490 58 5553 35 5616 53 5679 37 5741 92 5803 45 5865 06 5925 91N 838 11N 852 80 N 867 90 N 881 63 N 895 99 N 909 81N 924 O0 N 938 24 N 951 05 E 5490.25 N 8 47 E 56 E 5555.91 N 8 50 E 07 E 5621 08 N 8 52 E 37 E 5685 63 N 8 55 E 57 E 5749 80 N 8 58 E 97 E 5813 65 N 9 0 E 28 E 5876 95 N 9 3 E 08 E 5939 54 N 9 5 E 36 E 6001 13 N 9 7 E 11000 O0 8775.99 8725.99 36 48 N 12 46 E 6061 24 11100 O0 8856.12 8806.12 36 37 N 14 10 E 6120 89 11200 O0 8936,61 8886.61 36 14 N 14 4 E 6180 O1 11300 O0 9017.70 8967.70 35 22 N 13 40 E 6238 35 11400 O0 9099.49 9049.49 35 1 N 13 35 E 6295 63 11500 O0 9181.38 9131.38 35 1 N 13 35 E 6352 86 11525 O0 9201.85 9151.85 35 1 N 13 35 E 6367 17 1.81 5984 07 N 964 21 E 6061 26 N 9 9 E 0.64 6042 18 N 978 47 E 6120 90 N 9 12 E 0.27 6099 72 N 992 92 E 6180 O1 N 9 15 E 1.45 6156 55 N 1006 92 E 6238 35 N 9 17 E 0.00 6212 38 N 1020 42 E 6295 63 N 9 20 E 0.00 6268 17 N 1033 90 E 6352 87 N 9 22 E 0.00 6282 12 N 1037 27 E 6367 18 N 9 23 E COMPUTATION DATE: 11-JUN-93 PAGE 4 ARCO ALASKA, INC. P1 - 21 POINT MCZNTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 12-MAY-1993 KELLY BUSHING ELEVATION: 50.00 FT ENGINEER: d. MCCROSSAN INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH ~AST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 20O0 3000 4000 5000 60oO 7000 8000 9000 0 O0 -50 O0 0 0 N 0 0 E O0 1000 02 950 O0 1968 92 1918 O0 2818 34 2768 O0 3535 75 3485 O0 4258 34 4208 O0 5003 21 4953 O0 5732 89 5682 00' 6468 24 6418 O0 7260 98 7210 0..00 02 1'59 N 29 7 E 92 25 49 N 8 11 E 219 34 40 41 N 5 33 E 738 75 43 41 N 6 48 E 1433 34 43 7 N 7 55 E 2124 21 39 24 N. 7 10 E 2790 89 43 43 N 9 59 E 3473 24 39 25 N 7 22 E 4150 98 37 2 N 12 46 E 4759 0 10 33 31 27 07 57 66 56 61 0 O0 1 1 1 0 0 0 0 0 2 0 O0 N 98 0 O1 209 46 727 86 1419 24 2104 53 2765 56 3440 75 4110 79 4712 13 S 94 N 75 03 N 128 81 N 198 64 N 291 65 N 379 84 N 482 O0 N 585 44 N 675 0.00 E 1 45 E 1 18 E 222 94 E 738 81E 1433 45 E 2124 15 E 2791 93 E 3474 27 E 4151 20 E 4760 0 O0 N 0 0 E 46 S 84 42 E 99 N 19 42 E 37 N 10 3 E 66 N 7 58 E 72 N 7 53 E 52 N 7 48 E 57 N 7 59 E 47 N 8 6 E 56 N 8 9 E 10000.00 8006.39 7956.39 41 18 N 12 17 E 5424.24 11000.00 8775.99 8725.99 36 48 N 12 46 E 6061.24 11525.00 9201.85 9151.85 35 1 N 13 35 E 6367.17 0.28 5361.57 N 823.88 E 5424.50 N 8 44 E 1.81 5984.07 N 964.21 E 6061.26 N 9 9 E 0.00 6282.12 N 1037.27 E 6367.18 N 9 23 E ARCO ALASKA, INC. P1 - 21 POINT MC TNTYRE NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH '.DEPTH DEG COMPUTATION DATE: 11-JUN-93 PAGE 5 DATE OF SURVEY: 12-MAY-1993 KELLY BUSHING ELEVATION: 50.00 Fl' .:' ENGINEER: J. MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR cOoRDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0.00 0.00 -50.00 0 0 N 0 0 E 49.95 50.00 0.00 0 9 N 43 35 E 149.95 150.00 100.00 0 3 S 65 30 E 249.95 250.00 200.00 0 7 S 71 49 E 349..95 350..00 300.00 0 9 S 36 42 W 449:.95 450.00 400.00 0 9 S 12 22 E 549.95 550.00 500.00 0 12 S 12 3 E 649.95 650.00 600.00 0 18 S 9 40 E 749.95 750.00 700.00 0 20 S 6 27 E 849.95 850.00 800.00 0 11 S 11 7 E FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 O3 -0 03 0 -0 -0 -0 -~0 -1 -1 05 15 24 44 79 27 70 0 O0 1 82 0 36 0 08 0 21 0 44 0 43 0 59 0 53 0 35 0 O0 N 0 03 N 0 04 S 0 O1 N 0 20 S 0 28 S 0 49 S 0 85 S 1 34 S 1 78 S 0.00 E 0.01E 0.10 E 0.22 E 0.30 E 0.28 E 0.29 E 0.29 E 0.30 E 0.35 E 0.00 N 0 0 E 0.03 N 13 40 E 0.10 S 65 5 E O.22 N 87 26 E 0.36 S 56 31E 0.40 S 44 48 E 0.57 S 30 7 E 0..90 S 18 56 E 1.37 S 12 46 E 1.81 S 11 17 E 949 96 1050 1150 1251 1352 1455 1557 1660 1764 1870 950.00 900.00 03 1050/00 1000 O0 38 1150.00 1100 26 1250 O0 1200 92 1350 O0 1300 09 1450 O0 1400 66 1550 O0 1500 90 1650 O0 1600 87 1750 O0 1700 33 1850 O0 1800 1 4 N 32 46 E 3 24 · N 29 15 E O0 5 55 N 35 14 E O0 9 4 N 32 34 E O0 11 14 N 31 11E O0 12 21 N 23 3 E O0 13 26 N 17 53 E O0 15 10 N 17 31E O0 16 48 N 15 58 E O0 20 32 N 13 10 E -1 08 2 29 9 83 21 81 38 64 58 52 80 96 106 32 134 51 167 82 1 72 1 97 2 99 1 91 1 06 3 20 1 57 1 O6 2 56 4 41 1 8 19 35 53 75 99 126 159 1 23 S 90 N 8O N 74 N 21 N 75 N 25 N 69 N 87 N · 57 27 N 65 0 79 E 2 58 E 7 07 E 14 43 E 24 11E 33 83 E 41 48 E 49 1 46 S 32 47 E 3 11 24 42 63 85 16 E 111 56 E 139 87 E 172 20 N 53 38 E 29 N 38 45 E 45 N 36 10 E 68 N 34 24 E 51 N 32 11E 92 N 28 52 E 15 N 26 15 E 32 N 24 24 E 35 N 22 28 E 1979 02 1950 O0 1900.00 25 23 2090 2200 2312 2425 2541 2661 2784 2911 3041 09 2050 75 2150 37 225O 54 235O 20 2450 15 2550 03 2650 O0 2750 96 2850 O0 2000.00 25 39 O0 2100.00 25 25 O0 2200.00 27 19 O0 2300 O0 28 31 O0 2400 O0 32 18 O0 2500 O0 34 25 O0 2600 O0 37 6 O0 2700 O0 38 52 O0 2800 O0 41 26 N 8 32 E N 9 24 E N 9 46 E N 5 41E N 5 40 E N 3 30 E N 4 32 E N 5 16 E N 5 28 E N $ 2 E 210 27 258 60 305 98 355 50 408 39 466 26 532 20 603 37 681 42 765 78 3 22 1 O4 1 59 1 62 1 48 2 76 1 22 2 52 1 94 2 62 200.97 N 248.78 N 81 295.45 N 89 344.60 N 95 397 35 N 100 455 20 N 105 521 28 N 109 592 39 N 116 670 754 73 86 E 214.11 N 20 11 E O0 E 261,64 N 18 2 E 25 E 308.63 N 16 49 E 49 E 357.59 N 15 29 E 62 E 409~89 N 14 13 E 43 E 467.25 N 13 2 E 94 E 532.75 N 11 55 E 13 E 603.67 N 11 5 E 29 N 123.40 E 681.55 N 10 26 E 44 N 131.50 E 765.82 N 9 53 E 3178 06 2950.00 2900.00 43 37 3319 3462 3603 3742 3881 4019 4158 4298 4440 43 3050.00 3000.00 46 11 74 3150.00 3100.00 44 39 21 3250.00 3200.00 44 48 90 3350.00 3300.00 43 44 25 3450.00 3400.00 43 39 68 3550.00 3500.00 43 31 03 3650.00 3600.00 44 4 42 3750.00 3700.00 45 6 03 3850.00 3800.00 44 51 N 5 12 E 857 79 N 6 8 E 957 53 N 5 18 E 1059 94 N 5 48 E 1158 39 N 6 3 E 1255 74 N 6 30 e 1351 21 N 6 51E 1446 84 N 7 2 E 1542 36 N 7 37 E 1640.83 N 7 46 E 1741.06 1.46 1.50 0.99 0.07 0.2O 0.49 0.97 0.65 0.74 0.62 846.43 N 139.15 E 857.79 N 9 20 E 945.78 N 3.49 61 E 957 54 N 8 59 E 1047.98 N 159 1146.16 N 168 1243.17 N 178 1338.21N 189 1433.29 N 200 1528.21N 211 1625.94 N 224 1725.31N 237 25 E 1060 93 E 1158 91E 1255 32 E 1351 42 E 1447 86 E 1542 36 E 1641 81E 1741 O1 N 8 38 E 54 N 8 23 E 98 N 8 11E 53 N 8 3 E 23 N 7 58 E 82 N 7 54 E 35 N 7 51E 62 N 7 51E COMPUTATION DATE' 11-JUN-93 PAGE 6 ARCO ALASKA, INC. Pi - 21 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 12-MAY-1993 KELLY BUSHING ELEVATION' 50.00 FT ENGINEER' J. MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4579' 76 3950 O0 3900 O0 43 35 N 7 58 E 1838 61 4716 4852 4988 5125 5263 5400 5535 5668 5800 41 4050 19 4150 57 4250 79 4350 48 4450 12 4550 12 4650 43 4750 28 4850 O0 4000 O0 4100 O0 4200 O0 4300 O0 44O0 O0 45O0 O0 4600 O0 4700 O0 4800 O0 42 45 N 8 17 E 1931 O0 42 35 N 8 3 E 2023 O0 43 7 N 7 56 E 2116 O0 43 19 N 7 40 E 2210 O0 43 29 N 7 19 E 2304 O0 42 51 N .7 25 E 2397 O0 41 52 N 7 42 E 2488 O0 41 5 N 7 41 E 2576 O0 40 25 N 7 34 E 2662 I 32 1821 98 N 251 09 E 1839 20 N 7 51 E 72 0 56 0 26 0 2O 0 79 0 8,5 0 51 0 62 0 53 0 12 1914 64 2005 18 2096 29 2190 29 2283 50 2376 67 2466 26 2553 02 2638 15 N 264 41 E 1932 07 N 277 47 E 2024 90 N 290 37 E 2116 O0 N 303 12 E 2210 83 N 315 43 E 2305 18 N 327 38 E 2398 08 N 339.41 E 2489 43 N 351.21E 2577 60 N 362.66 E 2663 32 N 7 52 E 18 N 7 53 E 91 N 7 53 E 88 N 7 53 E 51 N 7 52 E 62 N 7 51 E 32 N 7 50 E 47 N 7 5O E 41 N 7 5O E 5931 01 4950 O0 4900 O0 39 44 N 7 21 E 2746.68 6O60 6192 6327 6465 6604 6744 6885 7023 7161 72 5050 46 5150 37 5250 18 535O 08 5450 54 5550 O0 5650 69 5750 96 5850 O0 SO00 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 39 49 N 7 13 E 2829.24 O0 41 29 N 8 2 E 2914.95 O0 42 59 N 8 17 E 3005.49 O0 43 39 N 8 27 E 3100 29 O0 44 7 N 9 0 E 3196 69 O0 44 56 N 9 37 E 3295 32 O0 44 16 N 9 56 E 3393 95 O0 43 48 N 9 59 E 3490 04 O0 43 38 N 10 16 E 3585 52 0 63 2722 08 N 373 61 E 2747 60 N 7 49 E 97 2804 92 2889 28 2978 68 3072 62 3167 15 3265 50 3362 50 3456 34 3550 05 N 384 07 N 395 7O N 4O8 50 N 421 82 N 436 13 N 452 33 N 469 98 N 485 98 N 502 O0 E 2830 18 E 2915 05 E 3006 85 E 3101 31E 3197 35 E 3296 12 E 3394 77 E 3490 57 E 3586 22 N 7 48 E 97 N 7 47 E 52 N 7 48 E 32 N 7 49 E 73 N 7 51 E 32 N 7 53 E 9O N 7 57 E 94 N 8 0 E 36 N 8 3 E 7300 54 5950 O0 5900 O0 44 4 N 10 15 E 3681 45 7439 7578 7712 7845 7976 8105 8233 8361 8487 70 6050 20 6150 79 6250 21 6350 36 6450 59 6550 99 6650 08 6750 10 685O O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 67O0 O0 6800 O0 43 56 N 9 49 E 3778 O0 43 20 N 8 16 E 3874 O0 41 7 N 6 49 E 3964 O0 40 44 N 6 44 E 4050 O0 39 35 N 7 5 E 4135 O0 39 2 N 7 33 E 4217 O0 38 36 N 7 47 E 4297 O0 37 45 N 7 41 E 4376 O0 37 19 N 7 24 E 4452 22 04 04 76 54 35 86 25 91 0 41 3645.38 N 53.9 72 E 3682.24 N 8 7 E 64 3740.69 N 536 92 3835.27 N 551 55 3924.62 N 563 08 4010.82 N 573 46 4095.09 N 583 40 4176.24 N 594 24 4256.06 N 604 72 4333.78 N 615 39 4409.81N 625 51E 3778.97 N 8 10 E 82 E 3874.77 N 8 11 E 17 E 3964.82 N 8 10 E 37 E 4051:60 N 8 8 E 38 E 4136.43 N 8 6 E 05 E 4218.28 N 8 6 E 83 E 4298.82 N 8 5 E 29 E 4377.24 N 8 5 E 39 E 4453.93 N 8 4 E 8612 16 6950 O0 6900 O0 36 28 N 7 38 E 4527 97 8736 8862 8986 9113 9245 9382 9520 9656 9791 60 7050 12 7150 26 7250 99 7350 78 7450 24 7550 93 7650 77 7750 31 7850 O0 7000 O0 37 8 N 9 6 E 4602 O0 7100 O0 36 47 N 10 35 E 4677 O0 7200 O0 36 41 N 12 34 E 4751 O0 7300 O0 40 13 N 13 41 E 4830 O0 7400 O0 40 53 N 14 45 E 4916 O0 7500 O0 44 27 N 12 52 E 5008 O0 7600.00 43 8 N 12 41 E 5104 O0 7700.00 42 9 N 12 16 E 5196 O0 7800.00 41 43 N 12 6 E 5286 O0 87 37 60 11 62 54 35 24 0 44 4484.27 N 635 09 E 4529 02 N 8 4 E 51 4557.56 N 645 42 4632.32 N 658 52 4704.38 N 673 42 4781.70 N 691 92 4864.88 N 712 94 4954.98 N 734 22 5048.70 N 756 04 5138.53 N 775 65 5226.50 N 794 70 E 4603 63 E 4678 38 E 4752 56 E 4831 72 E 4916 96 E 5009 16 E 5105 75 E 5196 78 E 5286 08 N 8 4 E 91 N 8 6 E 33 N 8 9 E 45 N 8 14 E 81 N 8 20 E 19 N 8 26 E O1 N 8 31E 76 N 8 35 E 58 N 8 39 E ARCO ALASKA, INC. P1 - 21 POINT MC INTYRE NORTH SLOPE, ALASKA COMPUTATION DATE: Il-JUN-93 PAGE 7 DATE OF SURVEY: i2-MAY-1993 KELLY BUSHING ELEVATION: 50.00 FT ENGINEER: J. MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE MEASURED YERTZCAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG MZN FEET DEG/IO0 FEET FEET FEET DEG MIN 9924 88 7950.00 7900.00 41 26 N 12 10 E 5374 68 10057 10190 10322 10453 10584 10713 10841 10967 11092 97 8050.00 8000 O0 41 11 N 12 26 E 5462 83 8150.00 8100 85 8250.00 8200 73 8350,.00 8300 05 8450.00 8400 44 8550.00 8500 48 8650.00 8600 58 8750.00 8700 38 8850.00 8800 O0 41 5 N 12 50 E 5549 O0 40 27 N 12 49 E 5635 O0 40 1 N 12 44 E 5720 O0 39 39 N 13 7 E 5803 O0 39 5 N 12 50 E 5885 O0 38 6 N 12 27 E 5965 O0 36 44 N 12 16 E 6041 O0 36 38 N 14 13 E 6116 0 32 5313 07 N 813 37 E 5374 97 N 8 42 E 38 0 70 0 74 0 02 0 42 0 36 0 18 1 88 1 36 0 11216.58 8950.00 8900.00 36 7 N 13 59 E 6189.¢6 11339,57 9050.00 go00.O0 35 1 N 13 35 E 6261.05 11461!.68 9150.00 glO0.O0 35 1 N 13 35 E 6330.93 11525.00 9201,85 9151.85 35 1 N 13 35 E 6367.17 !, 42 5398 46 5484 41 5568 71 5650 20 5732 54 5812 62 5890 66 5965 46 6037 89 N 832 23 N 851 27 N 870 63 N 888 09 N 907 08 N 926 11N 943 15 N 960 77 N 977 05 E 5462 62 N 8 46 E 22 E 5549 89 N 8 49 E 36 E 5635 89 N 8 53 E 98 E 5720 13 N 8 56 E 66 E 5803 51 N 9 0 E 17 E 5885 41 N 9 3 E 65 E 5965 22 N 9 6 E 02 E 6041.91 N 9 9 E 35 E 6116.37 N 9 12 E 1.37 6109.22 N 9'95.29 E 6189.76 N 9 15 E 0.00 6178.67 N 1012.28 E 6261.05 N 9 18 E 0.00 6246.80 N 1028.74 E 6330.94 N 9 21 E 0.00 6282.12 N 1037.27 E 6367.18 N 9 23 E ARCO ALASKA, INC. Pi - 21 POINT MCINTYRE NORTH SLOPE, ALASKA MARKER G~T LAST READING TD COMPUTATION DATE: 11-JUN-93 PAGE 8 DATE OF SURVEY- 12-MAY-1993 KELLY BUSHING ELEVATION: 50.00 FT ENGINEER: J. MCCROSSAN INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1379' FSL A 923' FEE, SEC16 T12N R14E MEASURED DEPTH -FVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11334.00 9045.49 8995.49 6175.58 N 1011.53 E 11525.00 9201.85 91S1.85 6282.12 N 1037.27 E ARCO ALASKA, iNC. P1 - 21 POINT MClNTYRE NORTH SLOPE, ALASKA MARKER COMPUTATION DATE: 11-JUN-93 PAGE 9 DATE OF SURVEY: 12-MAY-1993 KELLY BUSHING ELEVATION: 50.00 FT ENGINEER: J. MCCROSSAN ************ STRATIGRAPHZC SUMMARY SURFACE LOCATION = 1379' FSL ~ 923' FEL, SEC16 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11525.00 9201.85 9151.85 6282.12 N 1037.27 E FINAL WELL LOCATION AT l-D: ~ TRUE SUB-SEA' MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 11525.00 9201.85 9151.85 6367.18 N 9 23 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD POINT MClNTYRE WELL P1 - 21 COUNTRY USA RUN ONE DATE LOGGED i 2 - MAY - 93 DEPTH UNIT FEET REFERENCE 93234 All interprel:atlons ar~ opinions based on tn~'erences from electrical or other mea~urement~ and we cannot, and do not guarantee the accuracy or correctness of any Interpretations. end we shall not. except in tl-~ case of grc~e or wlh'ul[ negligence on our pe~rt be liable or relponsib~ for any loss. coats, damages or expensel incurred or sustair'~ed by anyone resultlr'~ fro~'n &ny interpretation rn&de by &ny of our officer~, e, gents or employees 'FT'~,e Interpretations ere also Subject to our (~emeral Terms and Conditions a~. set out in our current price ,~chedule I, ELL' P1-21 (1379' FSL, 923' FEL, SEC 16, T12N, R14E) .. VERTICAL PROJECTION 189.00 -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 . . . . : . ~ - . ~ . . : . . . x' l(iOO~ . . . . ....... : - ~ -. : . ~ .... : ............ :: :.- : : : ·-! . . : . . : . . . : :: :~ -.~: .:.~ -: 9O0 PROJECTION ON VERTICAL PLANE 189.00 9.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = I / 2000 IN/FT WELL' P1-21 (1379' FSL, 923' FEL, SEC 16, T12N, R14E) HORIZONTAL PROJECTION ~RTH 1 8OO0 6OO0 4000 2OO0 -2000 sou"n~ -4000 -8000 93234 S(~ALE - I / 2000 IN/FT · :: 'il ': ...... :';'';';";'::"F":'": .... ! !; ...... ! ...... ~ .... !'-i--','.!-! .... !'..! ...... ! .... ,---!--i ...... :- ,.:. , . .........................- : ~ I. ~ ................ ;..i-~...~ ...... i..~ ~- ..~..~.i 'i ...................... !'"i'-i"i .... i'"!."i-! ~ .... : ............. ; .... ! "; ....... ;";"'i ..... ''~ ~'":'"!'!'": ....... :'! ': :'i !'"i !"i ! i'!'-i.-.!- -i..i-i---i ..... i'"i-i-"i ...... i.-'i"i';--.!--;- i- - : ;.: : ; : : : .. :..;..; ...... ;:: ::,.- : -:. ::.::~::.:..: ::::.~::: ::: ......... : ! · : ! .... : .. ! ~ i. : : i. ; ~ ~ i : i ~ : ; ; i i i : ~ ; i ! i.i i ..i !.! i i i.: : ; i ';i; :;:;'!'i'!';i';?:'i'-i:-ii' ii!ii'iii--'!-i--!',i.-.i.-!-i..,i ..... ;-i-.i..i..i..;i..i-..~ .... i...i..,~ .... :.~.. ::;; . . .... : :::: ........... ~ !!!! i;;! ii:i iiii~-i!il _ '; ;";;";";;';';':;";";"";";'";":':';' "; ..... ;'i'i";'"!"Tt;'"~'~;"S;";'"?"i";";'"';;";';;;;;;i;'";' ;;;,' ;'": .... / ' ! ........... : : : .... ! : ' J ..... : ' ' : : i : "i ' ~ ' : :'1 i';'~ ' !' ' i .~.: :. . .~i, .'!. ;!. .::i., , , -6000 -4000 -2000 0 2000 4.000 6000 3000 VVEST EAST FINAL WELL REPORT PRUDHOE BAY DRILLING GROUP POINT McINTYRE P1-21/E6 NORTH SLOPE, ALASKA 30 APRIL 1993 TO 05 MAY 1993 RECEIVED OCT i 4 199;} ~as/<a Oil & (]as Go.s, Commission Anchorage ,., :-. ,, .!-Y"::i~. :-~ ! ~'..' '..., i-~.~".-',,~'- ~ · ~ !.,.~,,~.;.. ~ ..... THE INFORMATION, INTERPRETATIONS, RECOMMENDATIONS, OR OPINIONS CONTAINED HEREIN ARE ADVISORY ONLY AND MAY BE REJECTED. CONSULTANT DOES NOT WARRANT THEIR ACCURACY OR CORRECTNESS. NOTHING CONTAINED HEREIN SHALL BE DEEMED TO BE INCONSISTENT WITH, NOR EXPAND, MODIFY OR ALTER CONSULTANT'S OBLIGATION OF PERFORMANCE AS PROVIDED FOR IN A WRITTEN AGREEMENT BETWEEN THE PARTIES, OR IF NONE, IN CONSULTANT'S MOST RECENT PRICE LIST. EXPLORATION LOGGING OF USA, INC. COMPILED BY: DOUG FORSTER APPROVED BY: LARRY SHIELDS i( OI: ILHEI) TABLE OF CONTENTS ..... ~:,:,~ ~-~ :~ ~ ~' PAGE INTRODUCTION ' 1 i e e i e e e e · e · i · e · ~ e · · · i ~ e . I e e i · e ~ e ~ e e e I e e e e · i SUmmARY OF DATA ......................................... 2 METHODS OF: ............................................. 3 MUDLOG .......................................... 3 DRILL DATA ACQUISITION .......................... 3 COI~IUNICATIONS .................................. 3 SAMPLING PROCEDURES AND INTERVALS ............... 3 FORMATION EVALUATION WEST SAK LITHOLOGY ............................... 4 DRILL AND GAS DATA ...................... 5 OIL AND GAS SHOWS ....................... 5 HUE SHALES (K10,K5-SHALE WALL, HRZ,) LITHOLOGY ............................... 6 DRILL AND GAS DATA ...................... 6 OIL AND GAS SHOWS ....................... 6 KALUBIK AND KUPARUK LITHOLOGY ............................... 7 DRILL AND GAS DATA ...................... 7 OIL AND GAS SHOWS ....................... 7 APPENDIX I. SAMPLE DISTRIBUTION II. SHOW REPORTS III. BIT RECORD IV. INTEGRATED FORMATION LOG (MD), INTEGRATED FORMATION LOG (TVD), DRILLING DATA LOG, AND PRESSURE DATA LOG INTRODUCTION THE P1-21/E6 WELL IS ONE OF A SERIES OF POINT McINTYRE DEVELOPMENT WELLS, DRILLED ON THE POINT McINTYRE P1 PAD, APPROXIMATELY 12 MILES NORTH WEST OF PRUDHOE BAY, ALASKA. COORDINATES FOR THE SURFACE LOCATION OF THE WELL ARE: 1379' FSL & 923' FEL, IN SECTION 16, T12N, R14E UMIAT MERIDIAN. PROPOSED BOTTOM HOLE COORDINATES WERE: 2493' FSL & 210' FWL, IN SECTION 10, T12N, R14E UM. THE MAIN OBJECTIVE OF THIS WELL WAS THE THE KUPARUK RIVER FORMATION, A LOWER CRETACEOUS AGE MEMBER OF THE UGNURAVIK GROUP, AT A PROJECTED DEPTH OF 8764' SUB SEA TRUE VERTICAL. PROJECTED TARGET (KUPARUK RIVER) COORDINATES WERE: 2156' FSL & 151' FWL, IN SECTION 10, T12N, R14E UM. THE PROPOSED TARGET WAS REACHED BY DRILLING A DEVIATED HOLE; THROUGH THE USE OF DIRECTIONAL DRILLING TOOLS AND TECHNIQUES. SUCH THAT THE PROPOSED BOTTOM HOLE LOCATION WOULD BE NORTH EAST AT AN AZIMUTH OF 10 DEGREES, WITH A DEPARTURE OF 6150' WITH RESPECT TO SURFACE LOCATION. THE WELL PROGRAM WAS DESIGNED TO SET 10 3/4 INCH CASING AT 3992 FEET (3500 FEET TVD). THE REMAINDER OF THE HOLE WOULD BE DRILLED USING A 9 7/8 INCH BIT TO PROPOSED TD OF 11586 FEET (9142 FEET TVD). THIS "SLIM HOLE" DRILLING PROGRAM WOULD ELIMINATE AN INTERMEDIATE CASING RUN. THE PROJECTED STRATIGRAPHIC SEQUENCE PENETRATED BY THIS HOLE INCLUDED THE PERMAFROST, T-3, K-15, WEST SAK, K-10, HRZ, KALUBIK, AND KUPARUK RIVER FORMATIONS WITH PROPOSED FINAL WELL T.D. 100 FEET (MEASURED DEPTH) BELOW THE OIL-WATER CONTACT (OWC) IN THE KUPARUK RIVER FORMATION. -1- SUGARY OF PERTINENT DATA WELL NAME: API NUMBER: POINT McINTYRE P1-21/E6 50-029-22347 OPERATOR: PRUDHOE BAY DRILLING GROUP PARTNERS: ARCO ALASKA, BP EXPLORATION, AND EXXON CONTRACTOR: LOCATION: POOL ARCTIC ALASKA RIG #7 1379' FSL, 923' FEL SEC 16, T12N, R14E UMIAT MERDIAN ELEVATION: GROUND LEVEL 9' ABOVE SEALEVEL ROTARY KELLY BUSHING 41' ABOVE MEAN CASING: NONE SET WHILE EXLOG ON LOCATION DATE SPUDDED: 24 APRIL 1993 DATE TOTAL DEPTH REACHED: FINAL TOTAL DEPTH: 05 MAY 1993 11525' MD, 9202' TVD HYDROCARBON SHOWS: SEE SHOW REPORTS - APPENDIX II. EXLOG GEOLOGISTS: FINAL WELL STATUS: DOUG FORSTER, RALPH WINKELMAN, BILL STEVENS, RUN 7 5/8" LINER TO T.D. -2- METHODS GEOLOGIC AND DRILLING DATA WAS COLLECTED AT THE WELLLSITE USING EXLOG'S DRILL MONITOR SYSTEM (DMS). THE SYSTEM IS A COMPUTER BASED DATA COLLECTION UNIT, USED IN ACQUISITION, COMPILATION AND OUTPUT OF DATA. ADDITIONAL LITHOLOGIC AND HYDROCARBON EVALUATION WAS PROVIDED BY EXLOG'S ONSITE GEOLOGISTS. METHODS OF ANALYSIS USED FOR EVALUATION ARE PRESENTED IN EXLOG'S MANUAL "MUDLOGGING: PRINCIPLES AND INTERPRETATIONS" (MS-196). MUDLOG THE MUDLOG FORMAT WAS PREVIOUSLY ESTABLISHED ON FORMER POINT McINTYRE WELLS LOGGED BY THIS CREW. DATA DISPLAYED ON THE LOG INCLUDES: LITHOLOGY, RATE OF PENETRATION, TOTAL GAS, CUTTINGS GAS, CHROMATOGRAPH DATA, RESISTIVITY AND GAMMA RAY DATA WAS IMPORTED FROM TELECO AT THE END OF EACH BIT RUN. TOTAL GAS, RATE OF PENETRATION, CUTTINGS GAS AND GAMMA RAY ARE PLOTTED LINEARLY, WHILE ALL OTHER PARAMETERS ARE PLOTTED LOGARITHMICALLY. LOGS WERE PLOTTED AS 2 INCHES PER 100 FEET (1:600), WITH THE EXCEPTION OF THE PRESSURE DATA LOG. DRILL DATA DRILLING DATA MONITORED INCLUDED: RATE OF PENETRATION (ROP) USING THE BLOCK HEIGHT SYSTEM, ROTARY SPEED, HOOKLOAD, WEIGHT ON BIT, TORQUE (MINIMUM, MAXIMUM, AND AVERAGE), MUD FLOW IN AND OUT, MUD TEMPERATURE IN AND OUT, STANDPIPE PRESSURE, CASING PRESSURE, PUMP STROKES, AND ALL PITS WERE MONITORED. ALSO THREE H2S STATIONS WERE MONITORED AT ALL TIMES. THIS DATA WAS PLOTTED ON THE LOGS AS WELL AS BEING DISPLAYED ON REMOTE TERMINALS. COMMUNICATION EXLOG PROVIDED ONSITE AND OFF LOCATION REMOTE TERMINALS FOR THE DISPLAY OF ALL DRILLING PARAMETERS. THERE WAS A MODEM CONNECTION WITH A REMOTE TERMINAL IN THE DRILLING OFFICE. AN EXPLOSION PROOF DRILL MONITOR (HAD) WAS PROVIDED FOR THE DRILLER ON THE RIG FLOOR. SAMPLING SAMPLES WERE COLLECTED AT 30 FOOT INTERVALS FROM 8000' TO TD. THREE WET AND FIVE DRY SAMPLES WERE COLLECTED, AS WELL AS ONE SET OF SAMPLEX TRAYS. ALL SAMPLES WERE SHIPPED TO THE BAYVIEW GEOLOGIC FACILITY WAREHOUSE IN ANCHORAGE, IN CARE OF M.V. STANFORD. A COMPLETE LISTING OF SAMPLE SHIPMENTS CAN BE FOUND IN THE APPENDIX. -3- FORMATION EVALUATION LOGGING COMMENCED AT 1645 HOURS, APRIL 30, 1993 AT 6467 FEET TVD (8000 FEET MD) IN THE LATE CRETACEOUS. ALL DEPTHS, UNLESS OTHERWISE SPECIFIED, ARE REFERENCED FROM THE KELLY BUSHING WHICH WAS 50 FEET ABOVE SEA LEVEL. ALL FORMATION TOPS ARE UNCONFIRMED AND APPROXIMATE, AND BASED ON CUTTINGS EVALUATION. WEST SAK INTERVAL LITHOLOGY THE WEST SAK 6825' - 8325' TVD (8440'- 10430' MD) CLAY AND SILTSTONE WITH ABUNDANT VERY FINE TO COARSE GRAINED SAND CHARACTERIZED THE WEST SAK FORMATION. MINOR LIGNITE AND COAL INTER- BEDS WERE ALSO OBSERVED. THE MAJOR LITHOLOGIC COMPONENT OF THE WEST SAK WAS A LIGHT TO MEDIUM GRAY CLAY. THIS CLAY WAS OFTEN VERY SILTY AND AT TIMES SANDY. MINOR PYRITE AND BLACK LITHIC FRAGMENTS WERE ALSO PRESENT. SILT AND SILTSTONE IN THE FORMATION WAS VERY SIMILAR IN APPEARENCE TO THE CLAY. IN FACT, A GRADATION BETWEEN SILTY CLAYSTONE AND CLAY-RICH SILTSTONE, BEST DESCRIBES THE WEST SAK IN THIS WELL. SANDS IN THE WEST SAK WERE GENERALLY UNCONSOLIDATED. GRAIN SIZE RANGED FROM VERY FINE TO COARSE, AND GRAIN SHAPE WAS VARIABLE BUT PREDOMINANTLY SUB-ANGULAR. SORTING OF THE SANDS WAS POOR TO FAIR, WITH MATRIX COMPRISED OF ABUNDANT SILT AND CLAY. MINOR BLACK LITHIC FRAGMENTS WERE OBSERVED THROUGHOUT THE INTERVAL. THESE SANDS WERE COMMON ABOVE 7300 FEET TVD (9050 FEET MD). BETWEEN 7300 FEET AND 8325 FEET TVD (9050 AND 10430 FEET MD), THE LITHOLOGY CHANGED TO ALMOST ENTIRELY CLAY AND CLYASTONE WITH ASSOCIATED (AND SIMILAR) SILT AND SILTSTONE. VERY LITTLE SAND WAS SEEN IN THIS INTERVAL. -4- DRILL RATE AND GAS DATA THE DRILL RATES RANGED FROM 10 TO 600+ FEET PER HOUR THROUGH THIS HOLE SECTION. DRILL RATES WERE GENERALLY VERY ERRATIC UP TO A DEPTH OF 7300 FEET TVD (9050 FEET MD) AND AVERAGED 150'FEET PER HOUR. THIS IS LIKELY DUE TO THE VARIABLE SAND AND SILT CONTENT IN THE FORMATION. BELOW 7300 FEET TVD, DRILL RATES WERE MORE STABLE AND AVERAGED 90 FEET PER HOUR. DITCH GAS RANGED FROM 5 TO 200 UNITS IN THE UPPER (SANDY) PORTION OF THIS SECTION, AND AVERAGED 20 UNITS. AN 200 UNIT GAS PEAK OCCURRED AT 7270 FEET TVD (9015 FEET MD). CHROMATOGRAPH ANALYSIS OF THE DRILL GAS SHOWED THE FIRST OCCURRENCE OF C2+ GASSES AT 6895 FEET TVD (8545 MD). ABOVE THIS DEPTH ONLY METHANE (C1) WAS DETECTED. BELOW 7300 TVD (9050 MD) BACKGROUND GAS RANGED FROM 30 TO 200 UNITS, AVERAGING 50 UNITS. C1 THROUGH C4 WERE COMPONENT GASSES THROUGHOUT ALL OF THE LOWER (SILTIER) WEST SAK. OIL AND GAS SHOWS NO OIL OR GAS SHOWS WERE ENCOUNTERED IN THE UPPER (SANDY) SECTION. MINOR DULL YELLOW CUT FLUORESCENCE WAS OBSERVED IN ASSOCIATION WITH THE APPEARENCE OF HEAVIER GASSES IN THE LOWER PORTION OF THE WEST SAK. NO FREE OIL WAS OBSERVED. -5- HUE SHALE SECTION (K-10, STUMP ISLAND SAND, HRZ) LITHOLOGY THE HUE SHALE CONTAINING THE K-10, STUMP ISLAND SAND, AND THE HRZ WAS FIRST ENCOUNTERED AT APPROXIMATELY 8325 FEET TVD (10430' MD) AND CONTINUED TO 8750' TVD (10965' MD). IT CONSISTED FIRST OF THE K-10/STUMP ISLAND ZONE, WHICH WAS OBSERVED AT 8325 FEET TO 8450 FEET TVD (10430 TO 10605 FEET MD). THIS ZONE CONSISTED OF MINOR VERY FINE-GRAINED SAND IN A TUFFACEOUS MATRIX. MINOR INOCERAMUS PRISMS AND SHELL FRAGMENTS WERE ALSO PRESENT. THE PREDOMINANT LITHOLOGY IN THIS ZONE CONSISTED OF A SILTY CLAYSTONE. FROM 8450 TO 8720 FEET TVD (10605 TO 10930 FEET MD) VARIOUS K-SHALES WERE ENCOUNTERED. THESE "SHALES" APPEAR AS A GRAY TO GRAY BROWN SILTY CLAYSTONE IN CUTTINGS. THEY ARE CARBONACEOUS AND EXHIBIT MINOR CUT FLUORESCENCE. COMMON CREAM TO GRAY BLUE VOLCANIC TUFFS WERE ALSO ENCOUNTERED IN THIS ZONE FROM 8720 TO 8750 FEET TVD (10930 TO 10970 FEET MD), WAS THE HRZ. THIS VERY FISSILE DARK GRAY SHALE WAS SILTY WITH MINOR VOLCANIC ASH PRESENT AS INTERBEDS. THE SHALE APPEARRED MICRO MICACEOUS AND VERY CARBONACEOUS. FLUORESCENT CUTS WERE STRONGER AND EXHIBITTED A MILKY YELLOW COLOR. DRILL RATE AND GAS DATA THE DRILL RATES RANGED FROM 10 TO 200 FEET PER HOUR IN THIS HOLE SECTION. THE AVERAGE DRILL RATE WAS 90 FEET PER HOUR WHILE USING THE PDC BIT. DITCH GAS PEAKED AT 190 UNITS IN THE STUMP ISLAND SANDS. THROUGHOUT THE REST OF THIS INTERVAL DITCH GAS WAS FAIRLY STEADY THROUGHOUT THIS SECTION, RANGING FROM 40 TO 75 UNITS. C1 THROUGH C4 WERE PRESENT THROUGHOUT THIS INTERVAL. OIL AND GAS SHOWS A VERY MINOR SHOW WAS OBSERVED IN THE STUMP ISLAND SANDS. THE LACK OF ABUNDANT SAND WAS THE MAJOR FACTOR IN RATING THIS A POOR SHOW. DULL GOLD SAMPLE FLUORESCENCE AND YELLOW SOLVENT CUT FLUORESCENCE WERE OBSERVED THROUGHOUT THIS INTERVAL. TRACE OIL STAINING WAS OBSERVED IN THE STUMP ISLAND SANDS, WITH A SLIGHT TRACE OF FREE OIL (SEE SHOW REPORT #1 FOR DETAILS}. -6- ~ALUBI~ ~ND ~U~ARU~ SECTION LITHOLOGY THE NEXT SECTION COMPRISING THE KALUBIK AND KUPARUK FORMATIONS WERE ENCOUNTERED FROM 8750 TO 9202 FEET TVD (10965 TO 11525 FEET MD). THE KALUBIK WAS ENCOUNTERED FROM 8750 TO 8800 FEET TVD (10965 TO 11030 FEET MD). THE KALUBIK CONSISTED OF A MEDIUM BROWN SILTY AND SANDY CLAYSTONE, WITH ABUNDANT ASSOCIATED TUFF. MINOR CONGLOMERATIC PEBBLES WERE ALSO PRESENT. THE FIRST APPEARENCE OF GLAUCONITE WAS ALSO OBSERVED IN THE KALUBIK. CUT FLUORESCENCE WAS FAIR WITH TRACE OIL STAINING PRESENT ON THE SANDY FRACTION OF THE SAMPLES. A SHOW RATING OF TRACE CAN BE GIVEN THE KALUBIK. THE KUPARUK RIVER FORMATION (PRIMARY OBJECTIVE) WAS ENCOUNTERED AT 8800 FEET TVD (11030 FEET MD) AND CONTINUED TO TD AT 9202 FEET TVD (11525 FEET MD). IT CONSISTED PRIMARILY OF LOOSELY UNCONSOLIDATED SANDS TO FRIABLE SANDSTONE. THE SANDS WERE LIGHT BROWN OIL STAINED THROUGHOUT THE SECTION AND WERE VERY FINE TO MEDIUM GRAINED. THE SHAPE OF THE SAND GRAINS WERE HIGHLY VARIABLE FROM SUBANGULAR TO ROUNDED, AND THE SORTING WAS MODERATE. THE PREDOMINANT SAND GRAIN WAS A FINE GRAINED, SUBROUNDED, QUARTZ. THE SECTION CONTAINED A HIGH PERCENTAGE OF GLAUCONITE AT TIMES. ALSO PRESENT WAS SIDERITE NODULES AND CEMENT AND PYRITE. MINOR SHALE AND SILTSTONE WAS PRESENT THROUGHOUT THE SECTION, MORE PREVALENT NEAR THE TOP OF THE KUPARUK AND RETURNING AT TOTAL DEPTH OF THE WELL. DRILL RATE AND GAS DATA DRILL RATES FOR THE KALUBIK RANGED FROM 10 TO 50 FEET PER HOUR, AVERAGING 20 FEET PER HOUR. A BIT CHANGE WAS MADE FROM A PDC BIT TO A INSERT BIT IN THE MIDDLE OF THE KALUBIK. THIS RESULTED IN A SLOWING OF THE DRILL RATE, BUT DID NOT INDICATE A FORMATION CHANGE. DRILL RATES IN THE KUPARUK RANGED FROM 10 TO 50 FEET PER HOUR, AVERAGING 50 FEET PER HOUR. IT SHOULD BE NOTED THAT DRILL RATES WERE CONTROLLED THROUGHOUT MUCH OF THE KUPARUK TO FACILITATE MWD LOGGING. DITCH GAS IN THE KALUBIK RANGED FROM 50 TO 100 UNITS, AVERAGING 60 UNITS. DITCH GAS IN THE KUPARUK RANGED FROM 25 TO 190 UNITS, AVERAGING 150 UNITS. BLENDER GAS READINGS FOR THE KALUBIK AND KUPARUK MIRRORED THE OIL PRESENCE SEEN IN SAMPLES AND REACHED A PEAK OF 40 UNITS IN THE KUPARUK. C1 THROUGH C4 WERE PRESENT THROUGHOUT THE INTERVAL, WITH C3 AND C4 READINGS DECREASING BELOW 9100 FEET TVD (11410 FEET MD i THE DECREASE IN TOTAL GAS AS WELL AS HEAVIER GASSES IS PRESUMABLY DUE TO THE PENETRATION OF THE OIL WATER CONTACT. OIL AND GAS SHOWS THE KALUBIK EXHIBITTED A TRACE SHOW. THE KUPARUK EXHIBITTED A VERY GOOD TO EXCELLENT SHOW. THIS RATING WAS BASED ON THE ABUNDANT OIL STAINING, HIGH BACKGROUN] GAS INCREASE, AS WELL AS THE GOOD VISIBLE POROSITY EXHIBITTED IN THE SANDS. SEE TH] APPENDIX SHOW REPORT #2 FOR MORE DETAILS ON THE SHOW QUALITY. -7- SAMPLE SHIPMENTS FROM P1-21/E6 WET SAMPLES POINT MclNTYRE UNIT 242 POOL RIG #7 BOX # DEI~IVHS DATE SHIPPED FLIGHT # SHIPPERS INITIALS W1A 8000-9110 5/06/93 5172 5/06/93 WHS W2A I~3A 9110-10610 10610-11525 5/06/93 5/06/93 5172 5/06/93 5172 5/06/93 WHS WHS SAMPLE SHIPMENTS FROM P1-21/E6 DRY SAMPLES POINT McINTYRE UNIT 242 POOL RIG #7 BOX # DEPTHS DATE SHIPPED FLIGHT # SHIPPERS INITIALS D1A 5/06/93 WHS D2A ' 15172 5/06/93 8000-9800 , I I 9800-11525 I 5/06/93 15172 5/06/93 WHS SAMPLE SHIPMENTS FROM P1-21/E6 DRY SAMPLES - STATE POINT McINTYRE UNIT 242 POOL RIG #7 BOX # DEPTHS DATE SHIPPED FLIGHT # SHIPPERS INITIALS DIE D2E D3E ' 5/06/93 8000-9620 , ! ! 9620-11180 111180-11525 5172 5/06/93 5/06/93 5172 5/06/93 I 5/06/93 15172 5/06/93 ! I WHS WHS WHS SHOW REPORT #1 OIL COMPANY: PRUDHOE BAY DRLG. WELL NAME: P1-21/E6 LOCATION: NORTH SLOPE, AK DATE: 5/03/93 TIME: 12:42 SHOW INTERVAL: 10445'TO 10570'(MD) 8339' TO 8433' (TVD) BIT SIZE: 9.875" MUD WEIGHT: 9.8 ppg BIT TYPE: SEC SE1062 VISCOSITY: 60 PDC HOURS: 9.8 FILTRATE: 6.6 FEET: 825' EST. PORE PRES: 9.5 WOB: 25 klb LOGGING COND: GOOD RPM: 215 PUMP PR: 3400 PUMP SPM: 138 BEFORE DURING AFTER ROP 120 45* MIN 100 TOT GAS 100 195 MAX 100 C1 7000 22K 6800 C2 450 1300 600 C3 220 550 200 C4 145 280 130 C5 CHL 16K 16K 16K LITHOLOGY SILTSTONE: M GY - BRN SS: M BRN, VF - F GR, FRI -HD, SBANG, P SRTD SHALE: M - DK GY, PLTY OIL IN MUD: SLIGHT TRACE FLUOR: YELLOW UNWASHED CUT FLUOR: YELLOW - ORANGE WASHED CUT FLUOR: YELLOW - ORANGE STAIN: MED BRN SOLVENT CUT FLUOR: MILKY YELLOW - BLUE WHITE INTENSITY: DULL-BRIGHT TYPE & SPEED: SLOW STREAMING NAT COLOR & RESIDUE: PALE STRAW/ MEDIUM BRN VISUAL POROSITY: POOR COMMENTS: STUMP ISLAND. SECONDARY TARGET OF WELL. FRIABLE TO MODERATELY HARD SANDSTONE, IRREGULAR ROP INDICATE AN INTERBEDDED RESEVOIR. VERY POOR VISIBLE POROSITY, AND PREDOMINANCE OF SILT AND CLAY INDICATES PROBABLE POOR PERMEABILITY. POOR RATING. *NOTE: PDC BITS USUALLY EXHIBIT REVERSE DRILL BREAKS IN SANDSTONES. RATING: POOR LOGGING GEOLOGIST: D. FORSTER, R. WINKELMAN, B. STEVENS SHOW REPORT #2 OIL COMPANY: PRUDHOE BAY DRLG. WELL NAME: P1-21/E6 LOCATION: NORTH SLOPE, AK DATE: 5/04/93 TIME: 22:46 SHOW INTERVAL: 11030' TO 11525' (MD) 8800' TO 9203' (TVD) BIT SIZE: 9.875" BIT TYPE: SMITH F15CL HOURS: 2.0 MUD WEIGHT: 10.2 ppg VISCOSITY: 51 FILTRATE: 6.6 WOB: 25 klb LOGGING COND: GOOD RPM: 70 PUMP PR: 3300 FEET: 27' EST. PORE PRES: 9.6 PUMP SPM: 137 BEFORE DURING AFTER ROP 15 CONT. 50* N/A TOT GAS 40 175 MAX C1 2000 20K C2 150 1700 C3 80 800 C4 55 300 C5 CHL 17K 17K LITHOLOGY SILTSTONE: M GY - BRN SS: M BRN, VF - F GR, FRI, SBANG, W SRT STILL HAVE OIL STAIN AT TD, BUT BELOW OWC OIL IN MUD: TRACE SOLVENT CUT FLUOR: MILKY YELLOW FLUOR: YELLOW-GOLD INTENSITY: BRIGHT UNWASHED CUT FLUOR: YELLOW-GOLD TYPE & SPEED: INSTANT WASHED CUT FLUOR: YELLOW-GOLD NAT COLOR & RESIDUE: PALE STRAW STAIN: MED BRN VISUAL POROSITY: FAIR TO GOOD COMMENTS: KUP~A{UK IS THE MAIN TARGET OF THIS WELL. ABUNDANT OIL STAINING THROUGHOUT MOST OF THE INTERVAL. VERY GOOD, INSTANT CUT INDICATES FAIR TO GOOD POROSITY. GAS READINGS INCREASED REFLECTING VOLATILITY OF THE OIL. VERY GOOD TO EXCELLENT SHOW. *NOTE: DRILL RATE WAS CONTROLLED TO ACCOMODATE MWD LOGGING RATING: VERY GOOD - EXCELLENT LOGGING GEOLOGIST: D. FORSTER, R. WINKELMAN B. STEVENS 8IT D~ ~CORD ' RPM ' PUMP ' SPM/OPM' BIT _U_,' Bit I {(F]Z I TYPE ,' SIZE ' IADC I, JET ,' 8TA}~T I D}ZlLLED I AVG I WOB , , , , { ICODE ' SIZE I DEPTH { FT { HRS' ROP 'XlO00' ' PRESS' 'CO,ID t I r I I ~ { ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... ' 13114,12 ' 6938' ' 16,81 65 3 '5-55 I 215 ' 2850 ' 140/590 ' ' 3 ' HUOHES I ATJ )lOIS I 9 875", , I 1097, , , , I I ' ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... '4X14 I 8035' ' 20,0' 79,2 135-50' 215 ' 3250 ' 141/595 ' ' 4 ISEOUt~[TYI MS8P, J4 I 9 875"I , I 1584 , , , , , { ' I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... '7X12 ' 9619' ' 1384' 19 4' 71 4 ' 5'25' 215 ' 3400 ' 141/595 ' ' 5 ISECURIT¥',PDCSEi0621 9 875"I , , , , , , , , , , { , , , ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... ' 11003' ' I5 II 34 6 ',15-451 70 ' 3400 ' 140/590 ' ' 6 ' SMITH ' FiSCL I 9 875"I 13Xi4,13 , I 522 , , , , I I I ' ' ' ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I { I I I i I { I I I I I I I I I i I I I I I I I I I I I I .... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I .... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I { I I { I I I I I I I I I I I { I { I I I I { I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I I I I I I I I I I I I I I I I I I I I { .I I I I I I I { I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I I I I I I I I I I I I I { I I I i I I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I I ! I I I I I I I I I I I I I I I I I I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I I I I { I I f I I I I I I I I I I I I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I I I I I I I I I I I I I I I I I I { I I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I r I I I { I { I I I t I { I I I I I { I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... I { I { I I I I I I I I I I I I I I I I I I I I I I I I I I ..... + ..... + ........ + .......... + ........ + ...... + ......... + ......... + ....... + ..... + ....... + ..... + ..... + ...... + ......... + ..... Date: Subject: From: To: ARCO Alaska, Inc. ,.isburne/Point Mclntyre Engineering June 24, 1993 Transmittal #335, P1-21, Pl-16 & P1-02 (formerly PM#3) ARCO Alaska Inc. Bob Crandall AC)GCC 3001 Porcupine Drive Anchorage, AK 99501 The following Point'Mclntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log 1 blue line, 1 sepia P1-02 Compensated Neutron Log 2 1/2" CNT-D /P1-21 Gyro Directional Survey (GCT) Logy ~P1-21 Cement Bond Log (CBT) 10~00--INoO -~' \P1-21 Perforating Record Io~/oo-11~?~ Run # Run Date Company 6/11/93 Schlumberger 1 5/12/93 Schlumberger 1 5/13/93 Schlumberger 1 5/15/93 Schlumberger DISKETTE P1-16 Final GCT'/' P1-21 Final GCT Report Pl-16 Sub-Surface Directinoal Survey qb-~ P1-21 Sub-Surface Directinoal Survey Run # Run Date Company I 5/15/93 Schlumberger I 5/12/93 Schlumberger Run # Run Date Company I 5/15/93 Schlumberger I 5/12/93 Schlumberger Please Transmittal #335 and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 'xb'@ds Anchorage, Alaska 99510-0360 PLEASE SIGN ONE COPY AND RETURN TO: STATE of ALASKA OIL/GAS CON. COMM. 3001 PORCUPINE ANCHORAGE, ALASKA OPERATOR: ARCO DATE: 13 MAY, 1993 AIRBILL: 646137AL AFT#: 03-05-13-94 CHARGE CODE: 2C0034 NAME: PI 21 E6 SAMPLE TYPE: STATE DRIES NUMBER OF BOXES: 3 SAMPLES SENT: P! 21 E6 DRIES 8 0 0 0'-~J'2 5' SENT BY: Dan Przy~-vojski UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND SIGNED COPY OF THIS TRANSMITTAL TO: ARCO ALASKA, INC. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 ~ ~ ~ATTN: D. L. Przywojski ABV-IO0 RECEIVED BY: DATE :_~~~_~J MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David Johnstm'r~j~ date: Commissioner file: thru: Blair E Wondzell '(~~ subject: ,~"/~o/~ Petr Insp Supervisor from: ~oou Grimaldi Petr Inspector May 10, 1993 042493.doc Diverter Insp Pool Rig # 7 ARCO Well P1-21 Prudhoe Bay Unit PTD 93-59 Saturday. April 24, 1993: I witnessed the diverter function test on pool rig #7 preparing to drill ARCO's well PI-21 at Point Mcintyre. The rig had its diveder assembly ready to be function tested when ! arrived= ! fo_und _~_ _o! 7's diverter to be well laid out and to function properly. The annular preventer was fully closed within 42 seconds. The operation of the knife valves on the vent lines was quick and simultaneous. All flanges were bolted properly and the ventlines were secured. After operation of the diverter, the accumulator had 1600 psi remaining. A hydraulic leak at the annular preventer was noticed and repaired. Summary: I witnessed the diverter function test on pool rig #7 with all items in compliance. attachments UUU~ STATE OF ALASKA ALASKA b._ AND GAS CONSEP, VATION COMMISSION RIQ / BPS INSPECTION REPORT OF'ERA-i-ION: Drilling ,,~ ' Wore, over "Compl. UIC DATE: ~Well N~tme: ~...Z' - ¢7. ~ PTD#..~"~---g"~ Ddg Contractor: (~¢ ~. ,~ ¢C._~'-'f C Rig# 2. Rep. '..~-'//-1: )::),'z¢ ¢,//.~ S ¢/f--J Operator: '//~ ~ ¢__.. o ... Rep. ,Z_ ¢ ~ ¢~,,~'~' ~ Rig Ph.# Location: Section /~;~ T. {.~.,~. R. ,/;/¢'_~,¢' M. O/ " ii.~;~;::; (A.) B.O.P. STACK YES NO N/A i;iliiii!;i .(C.~) MUD SYSTEM YES NO N/A ;" W.z:'L.'_:: . , _, _ .i:i!~;i Wellhead fig wkg press )~', i:.~:~, Pit level flo~ts installed ~" i;;:2_ii! Slackwkg press. ~'~ i;~:~i¢ Flow raie sensor . i.;3:; An. nular p~eventer .,)~"' ;¢917( l~,iud g~s se.p~r~tor - :;;~;': Pipe r'~-n~ . .~ ;;~(:~ Uegesser .... .... ;!;~.....:.! G..as sensors :i-B'ii Ail turns targeted ( chke & kill Ln;) X '~i~.8;'] T.d.p. :?~ ........... ' ~ ;.~: , , , . - :P::::.: I .-.....[ ... ['"' F~ · '"'"' ;~,:'"t'F' .... :'-'" '"" '"'-'":'"' .' '*'""" ' ....... ' ' .;!.0 Manualvalves(chke&killLn.) - :i;¢:i(i?i _ (D.) RIG FLOOR YE,,~ NO N/A ;;i';i: C°nneciions (Flgd, Wt'd, CI~mped X *' i!~ !!.f' K.eiiy c. oc. ks (upper, iewer, IBOP) .i!~;Drilling spool "(' ;¢!~8), Floor v~tlves (dart, bell, ect.) ~ '" ;] :~i Flow Nipple 't/.., ,_ ;i.;3:§;;i Kelly & rio-or valve wrenches ::1/1~:~ Flow monitor )~ :i:~.8.; Driller¢ console (fieTM monil0r, _,~ r:¢i5: Control lines fire prote~;te'd ~ flow rote indict, tot, pit level ~;:::;?::i.: ::;i:ii'4§ .P...E:'-6--~jbN;i~E~¢i!¢iiii~¢ii!i i~"~O.B~LiANC.-'E;i; -~:~i-f indicators, gauges) , .::~:: ' ' ' ; ' L~% "-' i';L 'l' 't 'Q"_' C% "L';£1" i° ' i '-'1'-'-'"---' '.' :-i ..... - · -' · -i'-'F,-- -'-' .... ' -'-'- .:-' ;'-;- , [:,i;;'i;i.~. ..... (B.) CLOSING UNIT YES NO N/A ;::::.,;i Kill sheet up_zto-date - ,,~ .1..~6:IWorking pressure_ ' ' ' X ...... ;!."..4.2-: Gas detection monilors J:?: Fluid level ~ (H2S & methane) -- ;':i.:~i, Operating pressure y !~.~i: Hydre'ulic choke p~m .el :l?J Pressure ge. uges ~, !!~:]: Chok~ me. nifold ':-~:0' Su~iCientve~l',/es )6' i ii: !iiii~JB.~PED~tO~:ii~E~ei!i! ili!ii 1 ~;.~4~4,,~ ;::: ''O Lh'J~," ...... ';""" """'""""""-"""' ' 'LEt ........ '""5"""-' "' ',,~,'', ,', " ""';'-"".,' :.~:!.!Reguloto,'bypass .(;(i(;i;~ (E') MISC. EQUIPMENT YES NO N/A · , ,, ,:;~i~'j 4-w~ry'v'alves (actuators) F ;;~.5.;; Fie. re/vent line ,;~.~:' Blind rams handle cover ~¢ ~.i ;;~.~ Al' turn~, targeted ..... . ;~.~ Driller control panel ~k'~,,, .... (.downs!ream choke lines) ;;2.?Rernote conlrol panel tX ~;~:~i Reserve pit t~nk~ge .26'i Firewo. II ,~/. . "]~;; Personnel protedive equip. ev¢l. ,~ - - '2:~'! N,ttogen power source (backup)~_ ~:~.~;; All Drill~ile Supe~isors ~ined :;~]¢; Con.¢itjo~ (iy~s, hoses, e~) '~ ¢ _ For Procedures _ :~ :. ~2S probes _ _ . ~ii(~ Rig hoJsekeeping '" ,~' ,, RECORDS: ~.- ~ ~ Date of Lest Rig / BPS Inspedion Date of L~st BOP ~est Resulting Non-Compliance Items: Non-Compliance not correCed& Re,sun: ~ Date Corrections Will Be ~mpleled: ~ BOPTest & Results P~operly Entmed On Daily Record? Dislribution: orig - Well File c- Open/Rig c- D~l~bt~se c- Trip Rpt File c-Inspector ~ Sheet Culrent? FI-O22.XLT (Rev. 12/92) WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION April 21, 1993 Michael Zanghi Drilling'Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Point McIntyre P1-21 ARCO Alaska, Inc. Permit No: 93-59 Sur. Loc. 1379'NSL, 923'WEL, Sec. 16, T12N, R14E, UM Btmhole Loc. 2493'NSL, 210'EWL, Sec. 10, T12N, R14E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commis s ioner BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 ia.-[:yPe of work Drill [] Redrilll'-Illb. Type of well. Exploratoryr-'] Stratigraphic' Test r-I Development OilE] Re-Entry [] Deepenr"lI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) '10. Field and Pool ARCO Alaska, lnc: RTE- 50'feet Point Mc/ntyre 3. Address 6. Property Designation P. O. Box 196612. Anchora(~e. Alaska 99519-6612 ADL 34622 4. Location of well at surf-ace 7. unit or property Name 11. Type Bond(me 20 AAc 25.025) 1379' NSL, 923' WEL, SEC. 16, T12N, Ri4E Po/nt Mclnt, yre At top of productive interval 8. Well number Number 2156'NSL, 151'EWL, SEC. 10, T12N, R14E P1-21 U-630610 At total depth 9. APproximate spud date Amount 2493' NSL, 210' EWL, SEC. 10, T12N, R14E 4/19/93 $200,000. O0 12. DistanCe to nearest 13. Distance t'o nearest' well 14. Number of acres in property15. Proposed dePth(MDa,dmvD) property line ADL 28297-2493' feet P1-20-14' @ IO00'MD feet 2560 11586' MD/9142' TVD~e et r16. To be completed for deviated wells " 17. AnticiPated pressure (s~ 2o ,~c 2s.o3s !Kickoff depth 884feet Maximum hole an~!e 42 o Maximum surface 3330psig At total depth (TVD) 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of .c. ement Hole Casing Weight Grade COupling Length MD TVD" MD i'VD (include stage data) 26" 20" 91.5t/ H-40 Weld 80' Surface 80' 80' 281 cu ft Arcticset 13-1/2" 10-3/4" 45.5t/ J-55 B TC 3951' 41' 41' 3992' 3500' 2542cult 'E'/406 cu fl'G'/235 cu fl PF 'C' 9-7/8" 7-5/8" 29.7# VT95H[ NSCC 11545' 41' 41' 11586' 9142' 667cuftClass"G" , , 19. To be completed for Redrill, Re-entry, and Deepen'Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~--" ~ ';~ ...... '~ ~ "~ ~'~'~,?., Conductor ~',h ;~] ¢(. i-~' ~ ~.,"" Surface ;_,, ~ i.~' ~,,~ Intermediate Production ¢.,.~ ,, ; ,b Liner ~i;.,,::i~..:: ¢:., ¢, . ..... .., ,.-,.,....,i.,~.;~, Perforation depth: measured true vertical · !20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program'~ Drilling fluid program Ix-"! Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl-] 21.1 hereby ce~/~y ~foregoing is true and correct to the best of my knowledge Signed - . Title Drilling Eng. ineer Supervisor Date Commission Use Only Permit Number 'IAPI number IApP~val date See cover letter ~'.~_,~'"~, 150- © ~__ ¢- ~._ z. ~' ~ ,~ I .(_/L .-_;~/__.~ ~ for other requirements Conditions of a~proval samples required [] Yes ~No Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required [] Yes [] No Required working pressure for BOP._E__ r"]3M I~5M; I-I10M I-I15M; Other; oRIGINAL SIGNED B~ 2M' · ; by order of ,., .~',, Approved by . RUSSELL A. DOUGLAS~ Commissioner ~ne commission Date / Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN SUMMAF. WELL NAME: P1-21/E6 WELL TYPE: Slimhole, Iongstring AFE NUMBER: AFC #2C0034 INITIAL COMPLETION: Producer/water injector SURFACE LOCATION: 1379' FSL, 923' FEL, SEC 16, T12N, R14E TARGET LOCATION: 2156' FSL, 151' FWL, SEC 10, T12N, R14E BOTTOM HOLE LOCATION: 2493' FSL, 210' FWL, SEC 10, T12N, R14E TOTAL DEPTH: 11586' md / 9193' tvd brt CONTRACTOR: POOL 7 ELEVATION: RTE-SS: 50' RTE-GL: 41' GL-SS: 9' DIRECTIONAL INFORMATION: Typ. build and hold, target=8814' tvd brt, departure=6150'. KOP: 884' Angle/dir.: 42°/N10°E Build Rate: 2/100'md EOB: 2801' TVD/2984' MD MUD PROGRAM' Surface hole = typical spud mud. Production hole.(9-7/8")=3% KCL water. FORMATION MARKERS: TVDss MD STUMP ISLAND 8400 10586 TARGET (KUPARUK) 8764 11075 TD 9142 11586 MILUVEACH 9296 BELOW TD CASING PROGRAM: Hole Csg Wt Grade Conn Length Top 26" 20" 91.5 H-40 WELD 80 GL 13-1/2" 10-3/4" 45.5# J-55 BTC 3951 41 9-7/8" 7-5/8" 29.7# NT95HS NSCC 11545 41 Btm 80 " 3992(35ootvdss) 11586 Tbg Wt Grade COupling Length TOp 4-1/2" 12.6# L-80 TDS 10934 41 Btm 10975 LOGGING PROGRAM: Open Hole Logs; Surface NONE Final Mud Logs: Top of West Sak to TD. MWD: GR/Resistivity/Neutron/Density. Top of K-10 to TD Wireline: GR/Resistivity/Neutron/Density from top of West Sak to TD. Cased H01e Logs: Cement bond Icg and gyro after rig release. COMPLETION: 4-1/2" L-80 tubing with 2 GLM's (4-1/2" x 1") above top packer. Flapper type sub-surface saftey valve. I o , , . . o 10. , o MIRU drilling rig. P1-21/E6 Operations Summary Spud well and drill 13-1/2" hole to 3992' md/3550' tvd building angle to 42 degrees. Set 10-3/4" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 9-7/8" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to 11586' md / 9193 tvd. Run open hole logs. Set 7 5/8" casing and cement same, displacing with seawater. Test casing to 3500 psi for 30 minutes. Run 4-1/2" L-80 simple tubing completion and tree. Displace tubing to diesel and freeze protect well with 2000' of diesel in annulus. Release rig. Run cased hole logs: cement bond log, gyro. Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: P1-21/E6 Cement Volumes Surface String 3992 0 3/4 45.5 13.5 2 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 # sacks 1172 (2542 Cu. Ft.) TAIL (CLASS G) Yield 1.1 6 Density 15.8 # sacks 350 (406 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Intermediate String 11586 7 5/8 29.7 1 0075 9 7/8 1.9 LEAD Yield 1.98 Density 1 5 # sacks 0 # bbls 0 TAIL (CLASS G) Yield 1.1 6 Density 1 5.8 # sacks 5 7 5 # bbls I 1 9 (0 Cu. Ft.) (667 Cu. Ft.) A ' *' 0 ~,'-,-.. ~la~,k~.; Oil & Gm; Cons, P1-21 MUD PROGRAM SURFACE MUD PROPERTIES: TYPICAL Density Marsh Yield 10 sec 10 min (ppg) Viscosity Point gel gel Spud 8.7 300 40-60 30-60 60-80 T D 9.5 ' 100 20-40 15-20 20-30 Surface pH 9-10 9-10 Fluid Loss 15-25 15-25 FINAL HOLE MUD PROPERTIES: 3% KCL Density P V YP 10 sec 10 min pH (ppg) gel gel 10-3/4" 9.5 8-15 25-35 5-15 10-20 9-10 SHOE TD 10.0 15-30 25-35 8-12 <25 9-9.5 Fluid Loss 10-15 4-15 <12HTHP NOTE: ADJUST YP FOR HOLE CLEANING. MAINTAIN MINIMUM YP 25 FROM SURFACE CASING SHOE TO TD. _~ ¢ING DESIGN SPE(;IFICA' NS SURFACE CASING 10-3/4" 45.5#/FT, J-55. BTC BURST COLLAPSE PBYS # TJYS # J-55 3580 2090 715000 796000 . Burst Pressure The burst rating is based on shutting the well in on a gas kick with pressure equivalent to the leak-off at the surface casing shoe: Burst Pressure = 14 ppg (LOT) @ 3500' tvd = 2548 psi. Safety Factor = 1.41 Collapse Pressure The scenario for collapse rating is based on having lost circulation such that the fluid level drops below the surface casing shoe and there is 9.5 ppg mud in the annulus: Collapse pressure = 9.5 * 3500 * .052 = 1729 psi Saftey Factor = 1.21 3. Tension Tension is based on full string weight in mud. A maximum casing length of 4000' assumed, and a vertical hole is assumed (for worst case scenario): Tension = 45.5 * 4000 * .85 = 154700 Cf Saftey Factor (pipe body) = 4.62 Saffey Factor ~oint) = 5.15 PRODUCTION CASING 7-5/8", 29.7 #/FT, NT95H. S, 13CR80 NSOC BURST COLLAPSE PBYS # TJYS # 8180 7200 811000 813000 6890 4790 683000 721090 Burst Pressure The worst' case scenario is a tubing leak at reservoir pressure at the surface (with the NT95HS grade) with no annulus backup. Maximum shut-in tubing pressure= burst pressure= 4360 - (,15 * 9120') = 2992 psi Saftey Factor = 8180 / 2993 = 2.73 . Collapse Pressure Assume the casing is evacuated to gas lift gas with 10.0 ppg mud in the annulus (worst case on bottom with 13CR80 grade): Collapse pressure= 9120"10.0'.052 = 4742 psi Saftey Factor = 4790 / 4742 = 1.01 . Tension Based on a full string weight in 10 ppg mud. A maximum casing length of 11000' is assumed as a worst case scenario (at surface with NT 95HS grade): Tension = 29.7'11000'.85= 277,695 #. Saftey Factor = 811000 / 277695 = 2.92 Saftey Factor (joint) = 2.93 20'22'11" · . ~- PT. McINTYRE _ _ LEGEND ~ WE_LLS AS-BUILT THIS SURVEY m EXIS1]NG WELLS .] LOCATED WITHIN PROTRACTED SECTION 16, TI2N, R14E, UMIAT MERIDIAN, ALASKA P1-G1 P1-11 P1-19 P1-20 A.S.P. J PLANT C00RD.S. j COORDS. 5,994,380.57JN.~u=~=°~ .... ~q 674,661.52 E 3684.99 5,994,557.511 N 3000.11 674,275.88 E 3385.03 5.994.515.24I N 2999.70 67~,163.21 E 3264.69 5,994,510.22. iN 2999.85 674,149.29 E 3249.89 5,994,505.18iN 3000.09 674:134.99 E 3234.73 (;EODETIC POSI~ON 70'23'25. i04- ]48'34'44.675" 70'23'26.932" 148'34'55.844" 70'23'26.542" 148'34'59.171" 70'23'26.495" '~' '~G ~" 1~ 34 ~.j~ 70'23'26.450"~ I~uJJ CELLAR BOX EL. 9.2 8.8 9.2 9.6 9.3 p1-21 LOCATION IN SECTION 242' 400' FEL 1428' FSL 781' FEL I 1389' F5L 894' FEL 1384' FSL 908' FEL 1379' FSL 923' FEL.. 5/'8/92 :AS-2ButLT.i~ NORTH SLOPE PER ArE# 2C0001 ,_jMF RP I~'RAWN CHECK THIS SURVEY I VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE I hereby certify that I om properly registered and licensed to practice Land Surveying in the State of Alaska and that this plot represents o survey mode · by me or under my direct supervision and that oll dimension,'and other details are correct as of May 8, 1992. NOTES: 1. COORDINATES ARE BASED ON PT. M¢INTYRE MONUMENTS PM-1 EAST AND PM-1 W'EST AS ESTABLISHED BY F.R.BELL & ASSO~ 3,/1/92. 2. COORDINATES SHOWN ARE ALASKA STATE 'PLANE ZONE 4. 3. REFERENCE FIELD BOOK: PB 92-10 (P. 28-33). . 4. DATE OF SURVEY: MAY 7, 1992. 5. klEAN SCALE FACTOR -~ 0.9999344-8. F. ROBERT'BELL &: ASSOC- ARCO Alaska Inc. D R A',II1N 0 NAM,(.: PT. McINTYRE PM-i ..... CONDUCTOR AS-BUILT WELLS: PI-G1, -11, -19, -20 & -21, 5/8/92 I FENTIE I ~CALL: j "~."', ~: J A,~ F t': ..RP N.T.S. J J '2C0001 NSDP J 0000 ] CEA-4601-11213 PW/OA PM1 (;1 AB 201 or 1 { 0 / Prudhoe Bay Drilling Pain[ MoIntyre Well' # File' P -21WP HALLIBURTO~ ~N£RG¥ sr ~VlC DRILLING S Y s ¥ £ M s J HORIZONTAL VIEW SCALE 500 ft. /~DIVISION SURVEY REF: WET~LHEAD i 6500 3550 4000~ I 45007 5000 -- 5500-- 60004 6500 -- 7000 7500-- 8000-- 8450. 8500-- 8814 9000 -- 9119' 9193 3500 j VERTICAL VIEW SCALE 500 ft. / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD R,K.B. ELEVATION START OF BUILD 8 8.00 DEG/IO0 FT :30.08 deg, Eest Decllna~clon CRITICAL PBINT DATA HD Inc R,K.B. ELEVATION 0 0.00 START OF BUILD 884 0.00 8 2.00 DEG/IO0 FT END OF BUILD 8984 48 O0 10-3/4' CSG PT 3992 42 O0 STUMP ISLAND 10586 48 O0 TARGET/KUPARUK 11076 42 O0 TARGET/DUC 11486 48 O0 TBTAL DEPTH 11586 42 O0 Azi TVD North East 0.00 0 0 0 0.00 884 0 0 9,98 2801 725 127 9.92 3550 1389 243 9.98 8450 5735 1003 9.92 8814 6058 1060 9.92 9119 6389 1107 9,98 9193 6395 1119 736 END BF BUILD 1411 10.750 BD, 8 3998 MD, 3550 TVD 0.750 OD, 8 3998 HD I I 500 1000 1500 --6000 --5500 --5000 --4500 --4000 --3500 --3OO0 --2500 --2000 --1500 3550 TVD --1000 --500 CASING POINT DATA OD MD Inc Azi TVD North East 10.750 in. 3998 48.00 9.92 3550 1389 843 Dote Plotted Created By Checked By Approved By Date 4/13/93 BHL DATA J MD ~1585.sz/ v$ 8491.84/ North 6394.72! East 1118.74/ 5823 6150 6425 STUMP ISLAND TARGET/KUPARUK DUC I I I I o 500 lOOO 15oo 2ooo VERTICAL SECTION PLANE: 9.92' 6498 TOTAL DEPTH 8500 3000 3500 4000 4500 5000 5500 6000 6500 7~00 LLIBURTON DRILLING SYSTEMS Proposal Report Calt~lated uMng the Minimum Curvature Method Computed by the $ii Win-CADDS System Vertical Section Plane: 9.92 deg. Survey Reference: WELI_ItEAD Reference World Coordinate~: Lat. 70.23.26.45 N - Long. 14835.00.00 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinate~: (feet): 5994505.00 N 674135.00 E North Aligned To: TRUE NORTH Vertical Section Reference: WE~ Closure Reference: NVEL~ TVD Reference: ~WE~ Page 1 Date: 4/12/93 Time: 4:46 pm Wellpath II): PI-21WP Last Revision: 4/12/93 Prudhoe Bay Drilling Point Mclntyre Well: #PI-21 File: P1-21W'P Measured Incl Drift TVD Course Subaea T O T A L Depth Dir. Length Depth Rectangular O ff~ets (n) (dog.) (dog.) (ft) (rt) (ft) (ft) (ft) 1LICB. ELEVATION 0.00 0.00 0.00 0.00 0.00 -50.00 0.00N START OF BLrILD ~ 2.00 DEG/100 FT 883.71 0.00 0.00 883.71 883.71 833.71 0.00N 983.71 2.00 9.92 983.69 100.00 933.69 1.72N 1083.71 4.00 9.92 1083.54 100.00 1033.54 6.87N 1183.71 6.00 9.92 1183.115 100.00 1133.16 15.46N 1283.71 8.00 9.92 1282.41 100.00 1232.41 27.46N GRID Coordinates Northing Easting (ft) (ft) Closure Walk Build Vertical DLS DisL Dir. Rate Rate Section (ft) (deg.) (dg/lOOft) (dg/lOOft) (ft) (dg/lOOft) 0.00E 5994505.00 674135.00 0.00~ 0.00 0.00 0.00 0.00 0.00 0.00E 5994505.00 674135.00 030E 5994506.73 674135.26 0.00~ 0.00 0.00 0.00 0.00 0.00 1.75~ 9.92 0.00 2.00 1.75 2.00 1.20E 5994511.90 674136.04 6.98~ 9.92 0.00 2.70E 5994520.52 674137.34 15.69~ 9.92 0.00 4.80E 5994532.57 674139.16 27.88~ 9.92 0.00 1383.71 10.00 9.92 1381.17 100.00 1331.17 42.87N 7.50E 5994548.03 674141.50 43.52~ 9.92 0.00 1483.71 12.00 9.92 1479.33 100.00 1429,33 61.67N 10.79E 5994566.90 674144-35 62.60~ 9.92 0.00 1583.71 14.00 9.92 1576.76 100.00 1526.76 83.82N 14.66E 5994589.14 674147.71 85.10~ 9.92 0.00 1683.71 16,00 9.92 1673.35 100.00 1623.35 109.32N 19.12E 5994614.73 674151.57 110.98~ 9.92 0.00 1783.71 18,00 9.92 1768.97 100.00 1718.97 138.12N 24.16E 5994643.64 674155.94 140.21~ 9.92 0.00 1883.71 20,00 9.92 1863.52 100.00 1813.52 170.18N 29.77E 5994675.83 674160.80 172.77~ 9.92 0,00 1983.71 22.00 9.92 19515.87 100.00 1906.87 205.48N 35.95E 5994711.26 674166.15 208.60~ 9.92 0,00 2083.71 24.00 9.92 2048.92 100.00 1998.92 243.97N 42.68E 5994749.89 674171.99 247.67~ 9.92 0,00 2183.71 26.00 9.92 2139.55 100.00 2089.55 285.60N 49.96E 5994791.67 674178-30 289.93(~ 9.92 0.00 2283.71 28.00 9.92 2228.64 100.00 2178.64 330.31N 57.79E 5994836.56 674185.08 335,33~ 9.92 0.00 2383.71 30.00 9.92 23115.10 100.00 2266.10 378.07N 66.14E 5994884.49 674192-32 383.81~ 9.92 0.00 2483.71 32.00 9.92 2401.81 100.00 2351.81 428.80N 75.02E 5994935.41 674200.01 435316 9.92 0.00 2583.71 34.00 9.92 2485.68 100.00 2435.68 482.44N. 84.40E 5994989.26 674208.14 489.77~ 9.92 0.00 2683.71 36.00 9.92 2567.59 100.00 2517.59 538.94N 94.29E 5995045.97 674216.70 547.12tf~ 9.92 0.00 2783.71 38.00 9.92 2647.45 100.00 2597.45 598.22N 104.66E 5995105.47 674225.69 607,30(~ 9.92 0.00 2883.71 40.00 9.92 2725.16 100.00 2675.16 660.21N 115.50E 5995167.69 674235.09 670.23~ 9.92 0.00 END OF BUILD 2983.71 42.00 9.92 2800.62 100.00 2750.62 724.83N 126.81E 5995232.56 674244.88 735.84~ 9.92 0.00 10-3/4" CSG PT 3992.09 42.00 9.92 3550.00 1008.339 3500.00 1389.47N 243.08E 5995899.71 674345.63 1410.58~ 9.92 0.00 10585.69 42.00 9.92 8450.00 6593.60 8400,00 5735,45N 1003.40E 6000262.09 675004.13 5822.56~ 9.92 0.00 TARGETflCLrPARUI~ 11075.50 42.00 9.92 8814.00 489.81 8764,00 6058.29N 1059.88E 6000586.15 675053.03 6150.30~ 9,92 0.00 TARGET/OWC 11485.92 42.00 9.92 9119.00 410,42 9069.00 6328.81N 1107.21E 6000857.69 675094.00 6424.93~ 9,92 0.00 TOTAL DEPTH 11585.92 42.00 9.92 9193,31 100.00 9143.31 6394.72N 1118.74E ~000923.85 675103.99 6491.84,~ 9.92 0.00 2.00 6.98 2.00 2.00 15.69 2.00 2.00 27.88 2.00 2.00 43.52 2.00 2.00 62.60 2.00 2.00 85.10 2.00 2.00 110.98 2.00 2.00 140.21 2.00 2.00 172.77 2.00 2.00 208.60 2.00 2.00 247.67 2.00 2.00 289.93 2.00 2.00 335-33 2.00 2.00 383.81 2.00 2.00 435.31 2.00 2.00 489.77 2.00 2.00 547.13 2.00 2.00 607-30 2.00 2.00 670.23 2.00 2.00 735.84 2.00 0.00 1410.58 0.00 0,00 5822.56 0.00 0.00 6150,30 0.00 0.00 6424.93 0.00 0.00 6491.84 0.00 Pmud¼oe ]}o.y ]3mi//in9 Poi n-t; McTn ~yp e FiLe: P ~ -P J WP T~avelllng C~lincle~ - Lea~± Ref'er, ence ~ell - Pt-2JA/P TV]) 0 - 9193 ri:. Inter'vol, 50 'Ft. All ~r, ect;ions Rel "co Tr'ue Nor'th 330° 300° 600 550 5O0 450 400 350 3OO L::50 ~C)° 270° __ 9O° E4CP 120° 15~o CL~:~EST POINTS WetlL~th Slot Di~-tonce 'Oi~'ection Re£ MD ReF TVD Sep.Focto~ P:1-OI/PM7 P:1-0:1/PM7 4 50.L:~ 70.c)G :1 ~3.00 :150.00 479.00 PI -02/PM3 P J-D2/PM3 Eh59.38 97.55 J 556.16 ! 550.C0 22.F:~ P1-03/PN4 PI -03/PM4 270.37 70.97 50.00 50.00 1763.60 : , ~,-~o ,,.:~~.~,~ooo.o~ ~.co P2-O4VP P2-04 N/A N/A N/A N/A N/A P2-30CCT P8-30 N/A N/A N/A N/A N/A P2-48C_~T P2-48 N/A N/A N/A N/A N/A P2-4gGCT P2-49 N/A N/A N/A N/A N/A P~-5OCCT P~-50 N/A N/A NVA N/A N/A Fr2-51GCT P2-5:1 N/A N/A N/A N/A N/A P2-55CCT P2-55 N/A N/A N/A N/A N/A P2-57/PNI0 P2-57/PMI0 N/A N/A N/A N/A N/A P2-SS/P~6 P2-.58/P~ N/A N/A N/A N/A N/A PS-Sg/P~ P2-Sg/F~9 N/A N/A N/A N/A P~-60/PN 13 P2-60/PM J 3 N/A N/A N/A N/A N/A P~-D1 WP:1 P~-DJ N/A NWA NWA N/A N/A mi I=~1 317,~'7 9c),L:)0 17~ ~,47 1700,00 PM~ PM~ 317,~7 c)9.20 J7Jl,47 1700,C0 L;3,20 PM5 PM5 N/A N/^ N/A N/A N/A P~-~3WP P~-I3 ~eO.% 70,g5 0,00 0,00 ~L=O,60 CRITICAL POINT DATA T]E IN START D" ~JILD FT END ElF BUILD TARE~T TARGET MD ]nc Az; TVD No, ih Cost 0 0.00 O.CO 0 0 0 1~4 0.00 O.OO J~4 0 0 L::<284 42.00 9.9;3 L:>801 7c'-~ 127 :1:1076 42.00 g.g::2 13814 61358 :1060 :11486 42.00 9.c~ 9119 61k;~ 1:107 :1i586 42.00 9.92 9:193 6395 Ill9 Dote Rotted C~eo±ed Dy' Checked By Appr'oved~y : 4/12/93 : BH_ DATA TVD 9]93.3! MD I1,T~.9~ VS 6419,05 No~th 6394.7~ East 1118,74 Con.~ .ed by the Sii W/n-CADDS System Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling Point Mclntyre Well: # P 1-21 File: Pl-21WP N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Closest Points Wellpath P 1-01/PM 7 P1-02/PM3 P1-03/PM4 P1-04WP - pl-05wp P1-07/PM8 P1-08WP P1-08WPHW1 P1-11GCT P1-12/PM11 P1-14MWD p1-16mwd pl-17wp P1-20GCT P 1-25/PM 12 P 1 -G 1GCT P2-04WP P2-30GCT P2-48GCT P2-49GCT P2-50GCT P2-51GCT P2-55GCT P2-57/PM 10 P2-58/PM6 P2~59/PM9 P2-60/PM 13 P2-D1WP1 PM1 PM2 PM5 P1-13WP Slot P1-01/PM7 P1-02/PM3 P1-03/PM4 P1-04 P1-05 P1-07/PM8 P1-08 P1-08 P1-11 P1-12/PM11 P1-14 P1-16 P1-17 P1-20 P 1-25/PM 12 P1-G1 P2-04 P2-30 P2-48 P2-49 P2-50 P2-51 P2-55 P2-57/PM10 P2-58/PM6 P2-59/PM9 P2-60/PM 13 P2-D1 PM1 PM2 PM5 P1-13 Distance Direction Ref MD Ref TVD 450.25 70.96 150.00 150.00 269.38 97.55 1556.16 1550.00 270.37 70.97 50.00 50.00 255.05 70.91 50.00 50.00 240.19 70.86 50.00 50.00 186.06 97.23 1607.68 1600.00 170.84 98.72 1607.68 1600.00 170.84 98.72 1607.68 1600.00 150.15 70.62 450.00 450.00 135.13 70.99 50.00 50.00 104.87 71.21 400.00 400.00 74.68 70.96 0.00 0.00 52.26 101.33 1301.48 1300.00 14.38 94.61 1000.03 1000.00 59.97 251.05 50.00 50.00 540.56 104.70 350.00 350.00 5165.39 41.1011527.63 9150.00 8035.47 77.57 5001.32 4300.00 7740.87 80.22 5068.60 4350.00 7923.30 77.03 4732.19 4100.00 7746.52 80.68 5001.32 4300.00 6252.56 61.9411527.63 9150.00 3031.21 16.6911056.66 8800.00 6892.94 97.24 5674.13 4800.00 7388.75 80.44 6212.39 5200.00 7526.88 77.73 5539.57 4700.00 7622.99 77.44 4732.19 4100.00 6400.17 93.36 6481.51 5400.00 317.27 99.20 1711.47 1700.00 317.27 99.20 1711.47 1700.00 8048.23 132.11 0.00 0.00 120.56 70.95 0.00 0.00 Sep. Factor 479.0 22.6 1763.6 1397.6 1316.1 15.0 24.1 13.6 44.8 966.0 60.6 74.7 9.8 1.9 410.9 475.9 15.0 118.7 120.6 136.9 119.8 19.3 8.4 57.6 70.9 87.3 124.2 58.7 23.2 23.2 8048.2 120.6 6500 P~ud½oe ]~c~y ]3F~iL~ing Poi n -t; Mc]In -I;?F~ e Fi~e: P ~-2 i WP H[]~]Z[]WTAL VIEW (TRLE: SCALE J CID f±. / I]IV]S][]N SLRVEY Ik~iEF: WELLI-I::AD 70O --50O I ]00 2O9 I-~RIL 15 5/8"-5000PSi ¢~ ANNULA~ BoP LATCHEP HEAD CONNECT/ON ffYDRIL 1,3 5/8'- I O, O00PSi MPL I:~ BOP HUB CONNEOT/ONS 4 1/16'-10,000PSi SIDE OLffLETS HYDRIL 75 5/8'- IO, O00PSI MPL RAM BOP HUB CONNECTIONS 4. ?/?5'"-IO, O00PSI SIDE OLffLETS LYNN INTERNATIONAL HCR~ ~HCR ~'--5 1/16"-10,000PSI ~r ~' . K VALVE CHOKE WINO KILL WINO 5/8"-~o, oooPsi HUB X FLANGE HYDRIL 1,3 5/8'- I O, O00PSI MPL RA/vl BOP HUB CONNECTIONS 4 1/16"-10,000PSI SIDE OUTLETS BLOW-OUT PREVE~R STACK PM Rig 7 II Alibi *RUDHOEBAYDRILLING( ;::)UP 20" DIVERTER SCHEMA'I' lC POOL 7 FILL UP LINE . FLOWLINE Ji 20" 2000 PSI DIVERTER 10" BALL VALVE t CONDUCTOR I 10" BALL VALVE NOTE' ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE.OF THE SECO?-;D DiVERTER LINE. THE SECOND VENT LINE CAN BE REMOTELY DPENED TO ACHIEVE DOWNWIND DIVERS;iON. THIS IS A V'AR;A,NCE FROM 20AAC25.035. State: Alaska Borough: Well: P1-21 Field: PT, MCINTY'RE St. Perm # 93-59 R1-21CSG~J_S Date 4/14/93 Engr: M. Minder Casing Interval Interval Size Bottom Top lA 10.75 35O0 41 2A 7.625 9142 41 SA 0 0 0 4A 0 0 0 5A 0 0 0 GA 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Length $951 11545 0 0 0 0 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 45.5 J-55 BTC 0 29.7 NT95HS NSCC 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 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 819 9t9 1 OB Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/It psi/It 9.5 0.494 0.394 10.0 0,520 0.420 0.0 0,000 -0.100 0,0 0,000 -0.100 0.0 0.000 -0.100 0.0 0.000 .0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 8380 3580 1.1 3330 8180 ;2.5 0 0 #DIV/0! 0 0 #DIV/O.I 0 0 #DIV/O.I 0 0 #DIV/0! 0 0 #DIV/'0! 0 0 #DIV/0.1 0 0 #DIV/'O! 0 0 #DIV/O! Tension Strength K/Lbs 1C 179.7705 2C 342.8865 30 0 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 715 3.98 811 2.37 0 #DIV/O.I 0 #DIV/O! 0 #DIV/O.I 0 #DN/0! 0 #DIV/0.1 0 #DIV/0! 0 #DIV/O! 0 #DIV/0! Collapse Collapse Pr-Bot-Psi 1379 3840 0 0 0 0 0 0 0 0 Resist. CDF 2090 1.516 7200 1.875 0 #DIV/O! 0 #DIV/O.I 0 #DIViO.I o 0 #DIV/O! 0 #DIV/0! 0 #DIV/0! 0 Page 1 P1-21C~T.XLS Sta~e: A/~8 Engineer. Well: P1-21 Work Sheet: Field: PT. MCINTYRE Date: Sta~e Permit 1~ Cemsnl Vok~me Cslculalion~ 4/14/83 Casing Tj~pe Casing Size Ca,rig Lenglh Hote Diame~ Cement- Sacks Cema- Yield C~- Cu~ ~ Cema',{- C~c tt Cement- Sacks Cerr, ent- Yield Cement- Cubic ft Ceme. n~ - Cubic ft Cement- Sacks Cement-Yield Cement- Cubic ft Cement- Cul:~c fl Cernent - Cub~ fl / Vol Cement- Fill Factor -Inches · Feet -I~ ti1 111 ~I1 111 112 112 112 112 ~I3 113 ~I3 ~I3 ConducIo~ Surface 20.000 10.750 B0.000 3,951.000 26.000 13.500 0.000 0.000 0.000 0.000 0.000 0o000 281.000 2,542.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 406.000 0.000 0.000 0.000 0.000 281.000 2,948.000 2.333 2.051 Liner 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 IIOIV/O! Ca~g T;,pe Cas~g Size -Ir, cl-,~ Casing Depth - Feet Hole Diameter-Inches Cement-Sacks 111 Cement- Yield111 Cement- Cubic f~ 111 Cement-Cut~ ft 111 Cerne~- Sack~112 Cement- Yield112 Cement- Cubic ft 112 Cement- Cubic II 112 Cement-S~'ks 113 Cement- Yk~:i113 Cement- Cui~ fl 113 Cement- Cubic ft 113 Cement- Cubic ftt Vol Cerne~- interval fl Top of Cement- Feet Intamediale 111 Intermediate 112 0.000 0.000 0.000 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/i]!. 11DIV/O! I~DIV/O! 110IV/O! P~oduclion 7.625 11,586.000 9.875 0.00 0.00 0.00 667.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 667.00 3,105.89 8,480.1 Measured Depth Pdnted 4t14./93 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF ARCO ) ALASKA, INC. for an order ) granting an exception to ) spacing requirements of ) Title 20 AAC 25.055 to provide ) for the dr~]]ing of the ARCO Pt. ) McIntyre Well Nos. P1-04, Pl-16, ) Pl-17 and P1-21. ) Conservation Order No. 310 ARCO Alaska Inc. Pt. McIntyre Well Nos. P1-04, Pl-16, Pl-17 and P1-21 February 5, 1993 IT APPEARING THAT: ARCO Alaska, Inc. submitted applications dated January 12, 1993, requesting exception to 20 AAC 25.055(a)(3) to allow drilling the ARCO Pt. McIntyre Well Nos. P1-04, Pl-16, Pl-17, and P1-21 closer than 500 feet to a quarter section line. . Notice of hearing was published in the Anchorage Daily News on January 20, 1993 pursuant to 20 AAC 25.540. 3. No substantive protests to the applications were received. FINDINGS: , The ARCO Pt. McIntyre No. P1-04 well as proposed will be directionally drilled from a surface location 1463' from the south line (FSL), 683' from the east line (FEL) of Section 16, T12N, R14E, Umiat Meridian (U/VI), to a bottom-hole location 1010' from the north line (FNL), 13' FEL of Section 15, T12N, R14E, UM. The ARCO Pt. McIntyre No. Pl-16 well as proposed will be directionally drilled from a surface location 1404' FSL, 85g.' FEL of Section 16, T19.N, R14E, UM, to a bottom-hole location 660' FNL, 81' FEL of Section 10, T12N, R14E, UM. . The ARCO Pt. McIntyre No. Pl-17 well as proposed will be directionally drilled from a surface location 1399' FSL, 866' FEL of Section 16, T12N, R14E, UM, to a bottom-hole location 308' FNL, 1127' from the west line (FWL) of Section 15, T12N, R14E, UM. r Conservation February 5, 1993 Page 2 .r No. 310 e The ARCO Pt. Mcintyre No. P1-21 well as proposed will be directionally drilled from a surface location 1379' FSL, 923' FEL of Section 16, T12N, R14E, UM to a bottom-hole location 2468' FSL, 209' FWL of SecTion 10, T12N, R14E, UM. , Offset operators/owners Exxon Corporation and BP Exploration (Alaska) Inc. have been duly notified. An exception to 20 AAC 25.055(a)(3) is necessary to allow drilling each of these wells. CONCLUSION: Granting spacing exceptions to allow drilling of the ARCO Pt. McIntyre Well Nos. P1-04, Pl-16, Pl-17 and P1-2I as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: , ARCO Alaska, Inc.'s applications for exception to 20 AAC 25.055 for the purpose of drilling the Pt. McIntyre Well Nos. P1-04, P1- 16, Pl-17 and P1-21 are approved as proposed. DONE at Anchorage, Alaska and dated February 5, 1993. Commission · ~ Russell A. Douglass, C'~)inmissioner Alaska Oil and Gas Conservation Com~ssion ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee [ 2 ~hru (:3) Admin .[~)~ ~///~ ~/2¢.3 9. I]9 thru 13] 10. [10 & 13] 12. 13. [1~ ~hru 22] 15. [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (6) Other z~/f/ (//~/3:/J~-~ 2 9. [29 thru' -31'] 30. 31. (7) Con~ac~ [/~, ~3f~ ... 52. geology' eng i neet i rig' DWJ MTM//~ RAD~_~_-'~ ~ RPC/~4~ BEW JDH~I ~/t= LG rev 12/92 Company Lease & Well ~A~/- 3~g~."j /~/~_~.~//~.~r NO REMARKS YES 1. Is permit fee attached ............................................... ~ 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ...................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed ..................... ............... Is lease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or'production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety' in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ngrnber of contact to supply weekly progress data ...... ,// Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE //,~' $o Additional remarks' UM MERIDIAN' ~ - ' SM TYPE' Exp D~,~.v X Inj Redri 1 1 Rev 0 -H TZ ,--~0 Well History File APPENDIX Information of detailed nature that is not padiculady 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. US VERIFICATION USTING FOR: ARCO ALAStr~, INC. P1-21 POINT MCINTYRE RECEIVED DEC O 6 t99;5 Alaska Oii& Gas Cons. Cor~igissir~n Anchorage ATCM ATDC BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDCC PDEM RACM RADE ROPS ROPA RPCM RPDE SPOM TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR ARCO ALASKA P1-21 Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Bulk Density Compensated [RWD] Bulk Density Time Since Drilled [RWD] Conductivity (AT) Dielectric Corrected [RWD] Conductivity (PD) Dielectric Corrected [RWD] Calculated Dielectric Constant Density Long Space Apparent [RWD] Photoelectric Effect [RWD] Density Porosity Limestone Matrix [RWD] Density Porosity Sandstone Matrix [RWD] Delta Rho Correction [RWD] Density Short Space Apparent [RWD] Gamma Ray MEMORY (APl) [RWD] Neutron Porosity (LS) Borehole Corr [RWD] Neutron Far Base [RWD] Neutron Near Base [RWD] Neutron Porosity Time Since Drilled [RWD] Neutron Porosity (LS) [RWD] Neutron Porosity (SS) [RWD] Neutron Porosity Ratio Borehole Corr. [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected for Dielectric Effect [RWD] Rate of Penetration Rate of Penetration Averaged Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] Neutron Porosity (SS) Borehole Corr [RWD] CDS Temperature [RWD] AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling -dB -dB g/cc mins mmho/m mmho/m p.a. cps cps mins. p.u. p.u. p.u. degs degs mins ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m p.u. deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Thu 14 OCT 93 8:04a != = ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP I 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = I , ! Decode US Comment records: 0=OFF, I=ON 4 INFORECS = 1 , ! Decode US Information records: 0=NO, I=YES 5 MSTMETHOD = 0 , ! Usting Method: 0=depth units 1=tape units 6 MSTFREQ = 50, ! Usting Frequency: Every n units 7 MSTMAX = 0 , ! Usting Maximum (0=no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (1 =BIT,2=US ... thru 35=Array Accoustic) (see table) 10 WRITEASCll = 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) · 11 WRITETAP = I , ! WriteTape-lmage File: 0=NO, I=YES 12 SPMTLIS = 1 , ! If 1 and WRITETAP on, split US logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE ='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARA~ERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = I , INFORECS = 1 , USTMETHOD = 0 , LISTFREQ = 5O, USTMAX = 0, STATS -- 0, FORCETYP = 0 , WRITEASCII = 0 , WRITETAP = 1 , SPUTUS = 1, SUBFILES /0/, INTERPOLATE ='YES' END PROCESSING INTERVAL FROM 0.000 TO 0.000 .! !- CONSTANT PARAMETERS ALrTOCURV= O,O00000E+O0 Au'rOFILE= O.O00000E+O0 COMMENTS= 1.00000 FORCETYP= O,O00000E+O0 INFORECS= 1.00000 USTFREQ= 50,0000 LJSTMAX = O,O00000E+O0 USTMETH= O,O00000E+O0 SELFTEST= 0,000000E+00 SPL.ITLIS= 1.00000 STATS = O.O00000E+O0 WRITEASC= 0,000000E+00 WRITE'I'AP= 1,00000 dpcoef = 1,00000 dpcte = 1,00000 drlength= O.O00000E+O0 Iistwave= 0,000000E+00 maxrecln= O.O00000E+O0 minrecln= O.O00000E+O0 nsamptes= 0,000000E+00 numcurvs= 0.000000E+00 numdatar= O,O00000E+O0 numrecfl= O,O00000E+O0 tfendep = O.000(X)OE+O0 tflevsp = O,O00000E+O0 tfstdep = 0.000000E+00 wcrbot = 0.000000E+00 wcdevsp= O.O00000E + O0 wcrtop = O.O00000E + O0 !-- ARRAY PARAMETERS SUBFILES( 1):= O,O00000E+O0 SUBFILES( 3) =-9999,00 SUBFILES(5) =-9999,00 SUBFILES( 7) =-9999,00 SUBF~LES(9) =-9999.00 SUBFILES(11) = ~9999,00 SUBFILES(13) = -9999,00 SUBFILES(15) = -9999.00 SUBFILES(17) = -9999,00 SUBFILES(19) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(31) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(35) = -9999.00 SU, BFILES(37) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(41) = -9999,00 SUBFILES(43) = -9999.00 SUBFILES(45) = -9999.00 SUBFILES(47) = -9999,00 SUBFILES(49) = -9999.00 SUBFILES(51) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(55) = -9999,00 SUBFILES(57) = -9999.00 SUBFILES(59) = -9999,00 SUBFILES(61) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES(71) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(75) = -9999.00 SUBF~LES(77) = -9999.00 SUBFILES(79) = -9999,00 SUBFILES(81) = -9999.00 SUBFILES(83) = -99cJ9.00 SUBFILES(85) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(89) = -9999,00 SUBFILES(91) = -9999,00 SUBFILES(2) =-9999.00 SUBFILES(4) =-9999,00 SUBFILES(6) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(10) = -9999,00 SUBFILES(12) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(16) = -9999.00 SUBFILES(18) = -9999,00 SUBFILES(20) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(24) = .9999.00 SUBFILES(26) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES(30) = -9999,00 SUBFILES(32) = .9999.00 SUBFILES(34) = .9999,00 SUBFILES(36) = .9999.00 SUBFILES(38) = -99cJ9,00 SUBFILES(40) = -9999,00 SUBFILES(42) = -9999,00 SUBFILES(44) = -9999,00 SUBFILES(46) = -9999,00 SUBFILES(48) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(52) = .9999.00 SUBFILES(54) = -9999,00 SUBFILES(56) = -9999.00 SUBFILES(58) = .9999,00 SUBFILES(60) = .9999.00 SUBFILES(62) = -9999,00 SUBFILES(64) = -9999,00 SUBFILES(66) = -9999.00 SUBFILES(68) = -9999,00 SUBFILES(70) = -9999,00 SUBFILES(72) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(78) = -9999.00 SUBFILES(80) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(84) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(88) = -9999,00 SUBFILES(90) = -9999.00 SUBFILES(92) = -9999,00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 · SUBFILES(107) = -9999.00 SUBFILES(109) -- -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(I~5) ---9999.00 SUBFILES(117,), = -9999.00 SUBFILES(119)' ~=, -9999.00 SUBFILES(121) = :~r00 SUBFILES(123) = -9999,00 SUBFILES(125) = -9999;00 ~., SUBFILES(127) = -9999.00_ STRING PARAMETERS INTERPOL= YES SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(IO0) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(110) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(122) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(128) = -9999.00 Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\DATA\1213\1213,TAP (Output Tape-Image file will be over-written) Us'ting Method ("USTMETH") = 0, Depth Unit odented listing. Listing Frequency ("LISTFREQ") is every ( 50) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set USTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS= 1 to enable this feature) Automatic curve renaming has been disabled by user Input (AUTOCURV=0). Automatic "FILE= n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE= 1 to enable this feature) LIS comment record decoding (COMMENTS = 1) has been enabled by user Input. LIS information record decoding (INFORECS= 1) has been enabled by user Input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC= 1) Tape Subtile 1 is type: US **** REEL HEADER **** MWD 93/10/14 1213 01 **** TAPE HEADER **** MWD 93/10/13 1213 01 ; Tape Subtile: 1 Minimum record length: Maximum record length: 2 records.,. 132 bytes 132 bytes Tape Subtile 2 is type: LIS LIS COMMENT RECORD(s)' 123456789012345678901234567890123456789012345678..q012345678.9012345678901234567890 TAPE HEADER PRUDHOE BaY UNIT MWD/MAD LOGS # WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN1 BIT RUN2 JOB NUMBER: 1213 1213 LOGGING ENGINEER: T. FOSTER OPERATOR WITNESS: T. JOHNSTON BIT RUN4 BIT RUN5 JOB NUMBER: 1213 LOGGING ENGINEER: T. FOSTER OPERATOR WITNESS: T. JOHNSTON SURFACE LOCATION SECTION: 16 TOWNSHIP: 12N RANGE: 14E FNL: FSL: 1379 FEL: 923 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 50,00 GROUND LEVEL: 9.00 WELL CASING RECORD OPEN HOLE CASING P1-21 50-029-22363 Arco Alaska Inc, BAKER HUGHES INTEQ 12 0CT93 BIT RUN3 1213 R. GEHRES T. JOHNSON BIT RUN6 DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13,500 10.750 130.0 2ND STRING 9,875 4023.0 3RD STRING PRODUCTION STRING # REMARKS: $ R. MCCARTHY T. JOHNSON **** FILE HEADER **** MWD ,001 1 O24 LIS COMMENT RECORD(s): 123456789012345678901234567890123456789012345678,90123456789012345678901234567890 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 6873.0 11502.0 $ BASELINE CURVE FOR. SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) ~ EQUIVALENT UNSHIFTED DEPTH ...... BASELINE DEPTH BDCM BDEM CADE CPDE 6871.2 6850.0 6850.0 6850.0 6850.0 6850.0 10621.2 10600.0 10600.0 10600.0 10600.0 10600.0 10628.5 10604.0 10604.0 10604.0 10604.0 10604.0 10634.5 10610.0 10610.0.= 10610.0 10610.0 10610.0 10646.0 10621.5 10621.5 10621.5 10621.5 10621.5 10660.2 10635.7 10635.7 10635.7 10635.7 10635.7 10682.7 10681.7 10661.7 10661.7 10661.7 10661.7 10698.5 10675.7 10675.7 10675.7 10675.7 10675.7 10715.7 10692.7 10692.7 10692.7 10692.7 10692.7 10723.0 10702.2 10702.2 10702.2 10702.2 10702.2 10738.0 10716.0 10716.0 10716.0 10716.0 10716.0 10751.0 10729.5 10729.5 10729.5 10729.5 10729.5 10775.2 10753.7 10753.7 10753.7 10753.7 10753.7 10813.2 10791.5 10791.5 10791.5 10791.5 10791.5 10820.5 10798.0 10798.0 10798.0 10798.0 10798.0 · 10832.2 10809.5 10809.5 10809.5 10809.5 10809.5 10852.7 10829.0 10829.0 10829.0 10829.0 10829.0 10868.0 10845.2 10845.2 10845.2 10845.2 10845.2 10875.7 10853.5 10853.5 10853.5 10853.5 10853.5 10885.5 10862.7 10862.7 10862.7 10862.7 10862.7 10687.7 10865.7 10865.7 10865.7 10865.7 10865.7 10894.0 10872.2 10872.2 10872.2 10872.2 10872.2 10898.5 10876.7 10876.7 10876.7 10876.7 10876.7 10901.5 10878.7 10878.7 10878.7 10878.7 10878.7 10905.0 10883.0 10883.0 10883.0 10883.0 10883.0 10908.0 10885.0 10885.0 10885.0 10885.0 10885.0 10911.0 10888.2 10888.2 10888.2 10888.2 10888.2 10915.0 10890.7 10890.7 10890.7 10890.7 108,90.7 10920.2 10896.2 10896.2 10896.2 10896.2 10896.2 10921.7 10899.0 10899.0 10899.0 10899.0 10899.0 10928.0 10907.0 10907.0 10907.0 10907.0 10907.0 10930.0 10909.7 10909.7 10909.7 10909.7 10909.7 10936.2 10915.7 10915.7 10915.7 10915.7 10915.7 10941.2 10920.2 10920.2 10920.2 10920.2 10920.2 10944.2 10923.5 10923.5 10923.5 10923.5 10923.5 10947.2 10925.7 10925.7 10925.7 10925.7 10925.7 10950.5 10927.7 10927.7 10927.7 10927.7 10927.7 10953.0 10929.2 10929.2 10929.2 10929.2 10929.2 10954.2 10930.5 10930.5 10930.5 10930.5 10930.5 10958.7 10933.5 10933.5 109.33.5 10933.5 10933.5 10962.5 10937.5 10937.5 10937.5 10937.5 10937.5 10964.2 10939.5 10939.5 10939.5 10939.5 10939.5 DCCM 10977.7 10954,0 10954.0 10954.0 10954.0 10954.0 10979.0 10955,2 10955,2 10955.2 10955.2 10955.2 10981.5 10956.2 10956.2 10956.2 10956.2 10956.2 10981.7 10956.5 10956.5 10956.5 10956.5 10956,5 10982.0 10957.0 10957.0 10957.0 10957.0 10957.0 10986.0 10CJ61.0 10961.0 10961.0 10961.0 10961.0 10986.2 10961.5 10961.5 1096t.5 10961.5 10961.5 10991.7 10967.0 10967.0 10967.0 10967.0 10967.0 10992.2 10967.2 10967.2 10967.2 10967.2 10967.2 10992.7 10967.5 10967.5 10967.5 10967,5 10967.5 11000.2 10974.2 10974.2 10974.2 10974.2 10974.2 11009.5 10983.5 10983.5 10983.5 10983.5 10983.5 11018.7 10992.0 10992.0 10992.0 10992.0 10992.0 11039.7 11013.0 11013.0 11013.0 11013.0 11013.0 11048.7 11023.7 11023.7 11023.7 11023.7 11023.7 11054.2 11030.5 11030.5 11030.5 11030.5 11030.5 11060.7 11037.7 11037.7 11037.7 11037.7 11037.7 11073.2 11049.2 11049.2 11049.2 11049.2 11049.2 11078.5 11054.7 11054.7 11054.7 11054.7 11054.7 11094.5 11071.0 11071.0 11071.0 11071.0 11071.0 11099.7 11076.2 11076.2 11076.2 11076.2 11076.2 11113.5 11090.2 11090.2 11090.2 11090.2 11090.2 11119.7 11096.7 11096.7 11096.7 11096.7 11096.7 11127.5 11103.7 11103.7 11103.7 11103.7 11103.7 11138.2 11115.2 11115.2 11115.2 11115.2 11115.2 11144.2 11121.7 11121.7 11121.7 11121.7 11121.7 11152.0 11129.7 11129.7 11129.7 11129.7 11129.7 11161,7 11138.5 11138.5 11138.5 11138.5 11138.5 11181.0 11159.5 11159.5 11159.5 11159.5 11159.5 11204.2 11183.5 11183.5 11183.5 11183.5 11183.5 11212.2 11190.7 11190.7 11190,7 11190.7 11190.7 11241.7 11218.5 11218.5 11218.5 11218.5 11218.5 11246.0 11222.7 11222.7 11222.7 11222.7 11222.7 11257.5 11234.0 11234.0 11234.0 11234.0 11234.0 11270.7 11248.2 11248.2 11248.2 11248.2 11248.2 11319.0 11296.5 11296.5 11296.5 11296.5 11296.5 11328.2 11305.2 11305.2 11305.2 11305.2 11305.2 11349.2 11326.2 11326.2 11326.2 11326.2 11326.2 11392.0 11369.0 11369.0 11369.0 11369.0 11369.0 11397.5 11374.2 11374.2 11374.2 11374.2 11374.2 11407.7 11384.7 11384.7 11384.7 11384.7 11384.7 11550.0 11527.0 11527.0 11527.0 11527.0 11527.0 $ BASELINE DEPTH DLAM DPEM DPLM DPSM DRHM 6871.2 6850.0 6850.0 6850.0 6850.0 6850.0 10621.2 10600.0 10600.0 10600.0 10600.0 10600.0 10628.5 10604.0 10604.0 10604.0 10604.0 10604.0 10634.5 10610.0 10610.0 10610.0 10610.0 10610.0 10646.0 10621.5 10621.5 10621.5 10621.5 10621.5 10660.2 10635.7 10635.7 10635.7 10635.7 10635.7 10682.7 10661.7 10661.7 10661.7 10661.7 10661.7 10698.5 10675.7 10675.7 10675.7 10675.7 10675.7 10715.7 10692.7 10692.7 10692.7 10692.7 10692.7 10723.0 10702.2 10702.2 10702.2 10702.2 10702.2 10738.0 10716.0 10716.0 10716.0 10716.0 10716.0 10751.0 10729.5 10729.5 10729.5 10729.5 10729.5 10775.2 10753.7 10753.7 10753.7 10753.7 10753.7 10813.2 10791.5 10791.5 10791.5 10791.5 10791.5 10820.5 10798.0 10798.0 10798.0 10798.0 10798.0 10832.2 10809.5 10809.5 10809.5 10809.5 10809.5 10852.7 10868.0 10875.7 10885.5 10887.7 10894.0 10898.5 10901.5 10905.0 10908.0 10911.0 10915.0 10920.2 10921.7 10928.0 10930.0 10936.2 10941.2 10944.2 1O947.2 1O95O,5 1O953.O 1 O954.2 1O958.7 1O962.5 10964.2 10977.7 10979.0 1O981.5 10981.7 10982.0 1O986.0 10986.2 10991.7 10992.2 10992.7 11000.2 11009.5 11018.7 11039.7 11048.7 11054.2 11060.7 11073.2 11078.5 11094.5 11099.7 11113.5 11119.7 11127.5 11138.2 11144.2 11152.0 11161.7 11181.0 11204.2 11212.2 11241.7 11246.0 11257.5 10829.0 10845.2 10853.5 10862.7 10865.7 10872.2 10876.7 10878.7 10893.0 10885.0 10888.2 10890.7 10896.2 10899.0 10907.0 10909.7' 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 10829.0 10845.2 10&53.5 10862.7 10865.7 10872.2 10876.7 10878.7 10883.0 10885.0 10888.2 10890.7 10896.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.~ 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 10829.0 10845.2 10853.5 10862.7 10865.7 10872.2 10876.7 10878.7 10883.0 10885.0 10888.2 10890.7 10896.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 10829.0 10845.2 10853.5 10862.7 10865.7 10872.2 10876.7 10878.7 10883.0 10885.0 10888.2 10890.7 108,96.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 10829.0 10845.2 10853.5 10862.7 10865.7 10872.2 10876.7 10878.7 10883.0 10885,0 10888.2 10890.7 10896.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 11270.7 11248.2 11248.2 11248.2 11248.2 11248.2 11319.0 11296.5 11296.5 11296.5 11296.5 11296.5 11328.2 11305.2 11305.2 11305.2 11305.2 11305.2 11349.2 11326.2 11326.2 11326.2 11326.2 11326.2 11392.0 11369.0 11369.0 11369.0 11369.0 11369.0 11397.5 11374.2 11374.2 11374.2 11374.2 11374.2 11407.7 11384.7 11384.7 11384.7 11384.7 11384.7 11550.0 11527.0 11527.0 11527.0 11527.0 11527.0 $ BASELINE DEPTH DSAM GRAM GRCM 6871.2 6850.0 6850.0 6850.0 6850.0 10621.2 10600.0 10600.0 10600.0 10600.0 10628.5 10604.0 10604.0 10604.0 10604.0 10634.5 10610.0 10610.0 10610.0 10610.0 10646.0 10621.5 10621.5 10621.5 10621.5 10660.2 10635.7 10635.7 10635.7 10635.7 10682.7 10661.7 10661.7 10661.7 10661.7 10698.5 10675.7 10675.7 10675.7 10675.7 10715.7 10692.7 10692.7 10692.7 10692.7 10723.0 10702.2 10702.2 10702.2 10702.2 10738.0 10716.0 10716.0 10716.0 10716.0 10751.0 10729.5 10729.5 10729.5 10729.5 10775.2 10753.7 10753.7 10753.7 10753.7 10813.2 10791.5 10791.5 10791.5 10791.5 10820.5 10798.0 10798.0 10798.0 10798.0 10832.2 10809.5 10809.5 10809.5 10809.5 10852.7 10829.0 10829.0 10829.0 10829.0 10868.0 10845.2 10845.2 10845.2 10845.2 10875.7 10853.5 10853.5 10853.5 10853.5 10885.5 10862.7 10862.7 10862.7 10862.7 10887.7 10865.7 10865.7 10865.7 10865.7 10894.0 10872.2 10872.2 10872.2 10872.2 10898.5 10876.7 10876.7 10876.7 10876.7 10901.5 10878.7 10878.7 10878.7 10878.7 10905.0 10883.0 10883.0 10883.0 10883.0 10908.0 10885.0 10885.0 10885.0 10885.0 10911.0 10888.2 10888.2 10888.2 10888.2 10915.0 10890.7 10890.7 10890.7 108,90.7 10920.2 10896.2 10896.2 10896.2 10896.2 10921.7 10899.0 10899.0 10899.0 10899.0 10928.0 10907.0 10907.0 10907.0 10907.0 10930.0 10909.7 10909.7 10909.7 10909.7 10936.2 10915.7 10915.7 10915.7 10915.7 10941.2 10920.2 10920.2 10920.2 10920.2 10944.2 10923.5 10923.5 10923.5 10923.5 10947.2 10925.7 10925.7 10925.7 10925.7 10950.5 10927.7 10927.7 10927.7 10927.7 10953.0 10929.2 10929.2 10929.2 10929.2 10954.2 10930.5 10930.5 10930.5 10930.5 10958.7 10933.5 10933.5 10933.5 10933.5 10962.5 10937.5 10937.5 10937.5 10937.5 10964.2 10939.5 10939.5 10939.5 10939.5 10977.7 10954.0 10954.0 10954.0 10954.0 10979.0 10955.2 10955.2 10955.2 10955.2 10981.5 10956.2 10956.2 10956.2 10956.2 10981.7 10956.5 10956.5 10956.5 10956.5 10982.0 10957.0 10957.0 10957.0 10957.0 10986.0 10961.0 10961.0 10961.0 10961.0 10986.2 10961.5 10961.5 10961.5 10961.5 10991.7 10967.0 10967.0 10967.0 10967.0 LPOM 6850.0 1O6OO.O 10604.0 1O610.0 10621.5 1O635.7 10661.7 10675.7 10692.7 10702.2 10716.0 10729.5 10753.7 10791.5 10798.0 1O8O9.5 1O829.O 1O845.2 10853,5 10862.7 10865.7 10872.2 10876.7 1'0878.7 10883.0 10885.0 10888.2 10890.7 10896.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 NFBM 10992.2 10967.2 10967.2 10967.2 10967.2 10967.2 ,-. 10992.7 10967.5 10967.5 10967.5 10967.5 10967.5 11000.2 10974.2 10974.2 10974.2 10974.2 10974.2 11009.5 10983.5 10983.5 10983.5 10983.5 10983.5 11018,7 10992.0 10992.0 10992.0 10992,0 10992.0 11039.7 11013.0 11013.0 11013.0 11013.0 11013.0 11048.7 11023.7 11023.7 11023.7 11023.7 11023.7 11054.2 11030.5 11030.5 11030,5 11030.5 11030.5 ,- 11060.7 11037.7 11037.7 11037.7 11037.7 11037.7 11073.2 11049.2 11049.2 11049,2 11049.2 11049.2 11078.5 11054.7 11054.7 11054,7 11054.7 11054.7 11094.5 11071,0 11071,0 11071.0 11071.0 11071.0 11099.7 11076.2 11076.2 11076.2 11076.2 11076.2 11113.5 11090,2 11090,2 11090.2 11090.2 11090.2 11119.7 11096.7 11096.7 11096.7 11096.7 11096.7 =-- 11127.5 11103.7 11103.7 11103.7 11103.7 11103.7 11138.2 11115.2 11115.2 11115.2 11115.2 11115.2 11144.2 11121.7 11121.7 11121.7 11121.7 11121.7 -- 11152.0 11129.7 11129.7 11129.7 11129.7 11129.7 11161.7 11138,5 11138.5 11138.5 11138.5 11138.5 11181.0 11159.5 11159,5 11159.5 11159,5 11159.5 11204.2 11183.5 11183.5 11183.5 11183.5 11183.5 11212.2 11190,7 11190.7 11190.7 11190.7 11190.7 11241.7 11218.5 11218,5 11218.5 11218.5 11218.5 11246.0 11222.7 11222.7 11222..7 11222.7 11222.7 ~ 11257.5 11234.0 11234.0 11234.0 11234.0 11234.0 11270.7 11248.2 11248.2 11248.2 11248.2 11248.2 11319.0 11296.5 11296.5 11296.5 11296.5 11296.5 11328.2 11305.2 11305.2 11305.2 11305.2 11305.2 11349.2 11326.2 11326.2 11326.2 11326.2 11326.2 11392.0 11369.0 11369.0 11369.0 11369.0 11369.0 11397.5 11374.2 11374.2 11374.2 11374.2 11374.2 r~ 11407.7 11384.7 11384.7 11384.7 11384.7 11384.7 11550.0 11527.0 11527.0 11527.0 11527.0 11527.0 $ BASEUNE DEPTH NNBM NPEM NRCM PDEM 6871.2 6850.0 6850.0 6850.0 6850.0 6850.0 10621.2 10600.0 10600.0 10600.0 10600.0 10600.0 10628.5 10604.0 10604.0 10604.0 10604.0 10604.0 10634.5 10610.0 10610.0 10610.0 10610.0 10610.0 10646.0 10621.5 10621.5 10621.5 10621.5 10621.5 10660.2 10635.7 10635.7 10635.7 10635.7 10635.7 10682.7 10661.7 10661.7 10661.7 10661.7 10661.7 10698.5 10675.7 10675.7 10675.7 10675.7 10675.7 10715.7 10692.7 10692.7 10692.7 10692.7 10692.7 10723.0 10702.2 10702.2 10702.2 10702.2 10702.2 10738.0 10716.0 10716.0 10716.0 10716.0 10716.0 10751.0 10729.5 10729.5 10729.5 10729.5 10729.5 10775.2 10753.7 10753.7 10753.7 10753.7 10753.7 10813.2 10791.5 10791.5 10791.5 10791.5 10791.5 10820.5 10798.0 10798.0 10798.0 10798.0 10798.0 10832.2 10809.5 10809.5 10809.5 10809.5 10809.5 10852.7 10829.0 10829.0 10829.0 10829.0 10829.0 10868.0 10845.2 10845.2 10845.2 10845.2 10845.2 10875.7 10853.5 10853.5 10853.5 10853.5 10853.5 10885.5 10862.7 10862.7 10862.7 10862.7 10862.7 10887.7 10865.7 10865.7 10865.7 10865.7 10865.7 10894.0 10872.2 10872.2 10872.2 10872.2 10872.2 10898.5 10876.7 10876.7 10876.7 10876.7 10876.7 10901.5 10878.7 10878.7 10878.7 10878.7 10878.7 RACM 10905.0 10908.0 10911.0 10915,0 10920.2 10921,7 1 O928,0 10930.0 10936.2 10941.2 10944.2 10947.2 10950.5 10953.0 10954.2 10958.7 10962.5 10964.2 10977.7 10979.0 10981.5 10981.7 10982.0 10986.0 10986.2 10991.7 10992.2 10992.7 11000.2 11009.5 11018.7 11039.7 11.048.7 11054.2 11060.7 11073.2 11078.5 11094.5 11099.7 11113.5 11119.7 11127.5 11138.2 11144.2 11152.0 11161.7 11181.0 11204.2 11212.2 11241.7 11246.0 11257.5 11270.7 11319.0 11328.2 11349.2 11392.0 11397.5 11407.7 11550.0 10883.0 10885.0 10888.2 10890.7 10896.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 11248.2 11296.5 11305.2 11326.2 11369.0 11374.2 11384.7 11527.0 10883.0 10885.0 10888.2 10890.7 10896.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 11248.2 11296.5 11305.2 11326.2 11369.0 11374.2 11384.7 11527.0 10883.0 10885.0 10888.2 10890.7 10896.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 11248.2 11296.5 11305.2 11326.2 11369.0 11374.2 11384.7 11527.0 10883.0 10885.0 10888.2 1089O.7 1O896.2 10899.0 10907.0 10909.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 11090.2 11096.7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183.5 11190.7 11218.5 11222.7 11234.0 11248.2 11296.5 11305.2 11326.2 11369.0 11374.2 11384.7 11527.0 10883.0 10885.0 10888.2 10890.7 10896.2 108,99.0 10907.0 109O9.7 10915.7 10920.2 10923.5 10925.7 10927.7 10929.2 10930.5 10933.5 10937.5 10939.5 10954.0 10955.2 10956.2 10956.5 10957.0 10961.0 10961.5 10967.0 10967.2 10967.5 10974.2 10983.5 10992.0 11013.0 11023.7 11030.5 11037.7 11049.2 11054.7 11071.0 11076.2 1109O.2 11096,7 11103.7 11115.2 11121.7 11129.7 11138.5 11159.5 11183,5 1119O.7 11218.5 11222.7 11234,O 11248,2 11296.5 11305,2 11326.2 11369.0 11374,2 11384,7 11527.O $ BASELINE DEPTH 6871.2 10621.2 10628.5 10634.5 10646.0 10660.2 10682.7 10698.5 10715.7 10723.0 10738.0 10751.0 10775.2 10813.2 10820.5 10832.2 10852.7 10868.0 10875.7 10885.5 10887.7 10894.0 10898.5 10901.5 10905.0 10908.0 10911.0 10915.0 10920.2 10921.7 10928.0 10930.0 10936.2 10941.2 10944.2 10947.2 10950.5 10953.0 10954.2 10958.7 10962.5 10964.2 10977.7 10979.0 10981.5 10981.7 10982.0 10986.0 10986.2 10991.7 10992.2 10992.7 11000.2 11009.5 11018.7 11039.7 11048.7 11054.2 RADE ROPA ROPS RPCM RPDE 6850.0 6850.0 6850.0 6850.0 6850.0 10600.0 10600.0 10600.0 10600.0 10600.0 10604.0 10604.0 10604.0 10604.0 10604.0 10610.0 10610.0 10610.0 10610.0 10610.0 10621.5 10621.5 10621.5 10621.5 10621.5 10635.7 10635.7 10635.7 10635.7 10635.7 10661.7 10661.7 10661.7 10661.7 10661.7 10675.7 10675.7 10675.7 10675.7 10675.7 10692.7 10692.7 10692.7 10692.7 10692.7 10702.2 10702.2 10702.2 10702.2 10702.2 10716.0 10716.0 10716.0 10716.0 10716.0 10729.5 10729.5 10729.5 10729.5 10729.5 10753.7 10753.7 10753.7 10753.7 10753.7 10791.5 10791.5 10791.5 10791.5 10791.5 10798.0 10798.0 10798.0 10798.0 10798.0 10809.5 10809.5 10809.5 10809.5 10809.5 10829.0 10829.0 10829.0 10829.0 10829.0 10845.2 10845.2 10845.2 10845.2 10845.2 10853.5 10853.5 10853.5 10853.5 10853.5 10862.7 10862.7 10862.7 10862.7 10862.7 10865.7 10865.7 10865.7 10865.7 10865.7 10872.2 10872.2 10872.2 10872.2 10872.2 10876.7 10876.7 10876.7 10876.7 10876.7 10878.7 10878.7 10878.7 10878.7 10878.7 10883.0 10883.0 10883.0 10883.0 10883.0 10885.0 10885.0 10885.0 10885.0 10885.0 10888.2 10888.2 10888.2 10888.2 10888.2 10890.7 10890.7 10890.7 10890.7 10890.7 10896.2 10896.2 10896.2 10896.2 10896.2 10899.0 10899.0 10899.0 10899.0 10899.0 10907.0 10907.0 10907.0 10907.0 10907.0 10909.7 10909.7 10909.7 10909.7 10909.7 10915.7 10915.7 10915.7 10915.7 10915.7 10920.2 10920.2 10920.2 10920.2 10920.2 10923.5 10923.5 10923.5 10923.5 10923.5 10925.7 10925.7 10925.7 10925.7 10925.7 10927.7 10927.7 10927.7 10927.7 10927.7 10929.2 10929.2 10929.2 10929.2 10929.2 10930.5 10930.5 10930.5 10930.5 10930.5 10933.5 10933.5 10933.5 10933.5 10933.5 10937.5 10937.5 10937.5 10937.5 10937.5 10939.5 10939.5 10939.5 10939.5 10939.5 10954.0 10954.0 10954.0 10954.0 10954.0 10955.2 10955.2 10955.2 10955.2 10955.2 10956.2 10956.2 10956.2 10956.2 10956.2 10956.5 10956.5 10956.5 10956.5 10956.5 10957.0 10957.0 10957.0 10957.0 10957.0 10981.0 10961.0 10961.0 10961.0 10961.0 10961.5 10961.5 10961.5 10961.5 10961.5 10967.0 10967.0 10967.0 10967.0 10967.0 10967.2 10967.2 10967.2 10967.2 10967.2 10967.5 10967.5 10967.5 10967.5 10967.5 10974.2 10974.2 10974.2 10974.2 10974.2 10983.5 10983.5 10983.5 10983.5 10983.5 10992.0 10992.0 10992.0 10992.0 10992.0 11013.0 11013.0 11013.0 11013.0 11013.0 11023.7 11023.7 11023.7 11023.7 11023.7 11030.5 11030.5 11030.5 11030.5 11030.5 11060,7 11037.7 11037.7 11037.7 11037.7 11037.7 11073.2 11049.2 11049.2 11049.2 11049.2 11049.2 11078.5 11054.7 11054.7 11054.7 11054.7 11054.7 11094.5 11071.0 11071.0 11071.0 11071.0 11071.0 11099,7 11076.2 11076.2 11076.2 11076.2 11076.2 11113.5 11090.2 11090.2 11090.2 11090.2 11090.2 11119.7 11096.7 11096.7 11096.7 11096.7 11096.7 11127.5 11103.7 11103.7 11103.7 11103.7 11103.7 11138.2 11115.2 11115.2 11115.2 11115.2 11115.2 11144.2 11121.7 11121.7 11121.7 11121.7 11121.7 11152.0 11129.7 11129.7 11129.7 11129.7 11129.7 11161.7 11138.5 11138.5 11138.5 11138.5 11138.5 11181.0 11159.5 11159.5 11159.5 11159.5 11159.5 11204.2 11183.5 11183.5 11183.5 11183.5 11183.5 11212.2 11190.7 11190.7 11190.7 11190.7 11190.7 11241.7 11218.5 11218.5 11218.5 11218.5 11218.5 11246.0 11222.7 11222.7 11222.7 11222.7 11222.7 11257.5 11234.0 11234.0 11234.0 11234.0 11234.0 11270.7 11248.2 11248.2 11248.2 11248.2 11248.2 11319.0 11296.5 11296,5 11296.5 11296.5 11296.5 11328.2 11305.2 11305.2 11305.2 11305.2 11305.2 11349.2 11326.2 11326.2 11326.2 11326.2 11326.2 11392.0 11369.0 11369.0 11369.0 11369.0 11369.0 11397.5 11374.2 11374.2 11374.2 11374.2 11374.2 11407.7 11384.7 11384.7 11384.7 11384.7 11384.7 11550.0 11527.0 11527.0 11527.0 11527.0 11527.0 $ BASELINE DEPTH SPOM TCDM 6871.2 6850,0 6850,0 10621.2 10600.0 10600.0 10628.5 10604.0 10604.0 10634.5 10610.0 10610.0 10646.0 10621.5 10621.5 10660.2 10635.7 10635.7 10682.7 10661.7 10661.7 10698.5 10675.7 10675.7 10715.7 10692.7 10692.7 10723.0 10702.2 10702.2 10738.0 10716.0 10716.0 10751.0 10729.5 10729.5 10775.2 10753.7 10753.7 10813.2 10791.5 10791.5 10820.5 10798.0 10798.0 10832.2 10809.5 10809.5 10852.7 10829.0 10829.0 10868.0 10845.2 10845.2 10875.7 10853.5 10853.5 10885.5 10862.7 10862.7 10887,7 10865.7 10865.7 10894.0 10872.2 10872.2 10898.5 10876.7 10876.7 10901.5 10878.7 10878.7 10905.0 10883.0 10883.0 10908,0 10885.0 10885,0 10911.0 10888.2 10888.2 10915.0 10890.7 10890.7 10920.2 10896.2 10896.2 10921.7 10899.0 10899.0 10928.0 10907.0 10907.0 10930.0 10909.7 10909.7 10936.2 10915.7 10915.7 10941.2 10920.2 10920.2 10944.2 10923.5 10923.5 10947.2 10925.7 10925.7 10950.5 10927.7 10927.7 10953.0 10929.2 10929.2 10954.2 10930.5 10930.5 10958.7 10933.5 10933.5 10962.5 10937.5 10937.5 10964.2 10939.5 10939.5 10977.7 10954.0 10954.0 10979.0 10955.2 10955.2 10981.5 10956.2 10956.2 10981.7 10956.5 10956.5 10982.0 10957.0 10957.0 10986.0 10961.0 10961.0 10986.2 10961.5 10961.5 10991.7 10967.0 10967.0 10992.2 10967.2 10967.2 10992.7 10967.5 10967.5 11000.2 10974.2 10974.2 11009.5 10983.5 10983.5 11018.7 10992.0 10992.0 11039.7 11013.0 11013.0 11048.7 11023.7 11023.7 11054.2 11030.5 11030.5 11060.7 11037.7 11037.7 11073.2 11049.2 11049.2 11078.5 11054.7 11054.7 11094.5 11071.0 11071.0 11099.7 11076.2 11076.2 11113.5 11090.2 11090.2 11119.7 11096.7 11096.7 11127.5 11103.7 11103.7 11138.2 11115.2 11115.2 11144.2 11121.7 11121.7 11152.0 11129.7 11129.7 11161.7 11138.5 11138.5 11181.0 11159.5 11159.5 11204.2 11183.5 11183.5 11212.2 11190.7 11190.7 11241.7 11218.5 11218.5 11246.0 11222.7 11222.7 11257.5 11234.0 11234.0 11270.7 11248.2 11248.2 11319.0 11296.5 11296.5 11328.2 11305.2 11305.2 11349.2 11326.2 11326.2 11392.0 11369.0 11369.0 11397.5 11374.2 11374.2 11407.7 11384.7 11384.7 11550.0 11527.0 11527.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 6873.0 MWD 4 7987.0 MWD 5 9572.0 MWD 6 10955.0 MERGE TOP 7987.0 9572.0 10955.0 11502.0 MERGE BASE $ # REMARKS: DATA IN THIS FILE WAS DEPTH SHIFTED TO SCHLUMBERGER WIRELINE GAMMA RAY DATA, CN : Arco Alaska Inc, WN : P1-21 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 123456789012345678.901234567890123456789012345678.90123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA THAT WAS DEPTH SHIFTED, * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0 000000 1 000 1 Rep Code Count Bytes 68 10 40 Sum: 10 40 40 fndun a [F ] 1.00000000 ONE DEPTH PER Fi:tAME Tape depth ID: F 10 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 RHOBMWD 68 1 G/CC 4 4 98 660 71 6 2 PEF MWD 68 I BN/E 4 4 98 660 71 6 3 DRHOMWD 68 1 G/CC 4 4 98 660 71 6 4 GR MWD 68 I GAPI 4 4 98660 71 6 5 FCNTMWD 68 I CPS 4 4 98 660 71 6 6 NCNTMWD 68 1 CPS 4 4 98 660 71 6 7 NPHIMWD 68 I PU-S 4 4 98 660 71 6 8 IRA MWD 68 1 OHMM 4 4 98 660 71 6 9 ROP MWD 68 I FPHR 4 4 98 660 71 6 10 RP MWD 68 1 OHMM 4 4 98 660 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length Indicates: 23 FRAMES * DATA RECORD (TYPE# O) 1018 BY'rES * Total Data Records: 403 Tape File Start Depth = 6873,000000 Tape File End Depth = 11502.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER LIS representation code decoding summary: Rep Code: 68 14200 datums Tape Subtile: 2 994 records,., Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 3 is type: US **** FILE HEADER **** MWD .002 1024 US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 6894.0 7987.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (i=r): Bo'FrOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 30 APR 93 M1.33 M1.33 MEMORY 0.0 6894.0 7987.0 0 2.7 10.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 1678-17 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL POLYMER MUD DENSITY (LB/G): 9.10' MUD VISCOSITY (S): 56.0 MUD PH: 9,9 MUD CHLORIDES (PPM): 15(X)0 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: 0.250 MUD CAKE AT MT: 0.000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 9.875 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: $ CN : Arco Alaska Inc WN : P1-21 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska 0.000 0.0 O. 150 122.0 122.0 0,0 LIS COMMENT RECORD(s): 123456789012345678,90123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 3. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 32 128 Sum: 32 128 128 fndun a [F ] 1.130000000 ONE DEPTH PER FRAME Tape depth ID: F 32 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCM MWD 68 1 -dB' 4 2 ATDC MWD 68 1 -dB 4 3 BDCM MWD 68 1 G/CC 4 4 BDEM MWD 68 1 MINS 4 5 CADE MWD 68 I MMHO 4 6 CPDE MWD 68 1 MMHO 4 7 DCCM MWD 68 1 4 8 DLAM MWD 68 1 G/CC 4 9 DPEM MWD 68 1 MINS 4 10 DPLMMWD 68 1 PU 4 11 DPSMMWD 68 1 PU 4 12 DRHMMWD 68 1 G/CC 4 13 DSAMMWD 68 1 G/CC 4 14 GRAM MWD 68 1 GAPI 4 15 LPOMMWD 68 1 PU 4 16 NFBM MWD 68 I CPS 4 17 NNBMMWD 68 I CPS 4 18 NPEM MWD 68 1 MINS 4 19 NPLMMWD 68 1 PU 4 20 NPSM MWD 68 I PU 4 21 NRCM MWD 68 1 RAT 4 22 PDCM MWD 68 1 DEG 4 23 PDDC MWD 68 I DEG 4 24 PDEM MWD 68 1 MINS 4 25 RACM MWD 68 1 OHMM 4 26 RADE MWD 68 1 OHMM 4 27 ROPA MWD 68 1 FPHR 4 28 ROPS MWD 68 1 FPHR 4 29 RPCM MWD 68 I OHMM 4 30 RPDE MWD 68 1 OHMM 4 31 SPOM MWD 68 1 PU 4 32 TCDM MWD 68 1 DEGF 4 _ 128 498660 71 6 49866O 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 9866O 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 § 498660 71 6 498660 71 6 4 98660 71 '6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 9866O 71 6 498660 71 6 49866O 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 °' Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# O) 930 BYTES * Total Data Records: 625 Tape File Start Depth = 6894,000000 Tape File End Depth = 7987.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 25046 datums Tape Subflle: 3 690 records,.. Minimum record length: 62 bytes Maximum record length: g30 bytes Tape Subtile 4 is type: LIS **** FILE HEADER **** MWD .003 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 7987.0 9572.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): mD DRILLER (F-r): TOP LOG INTERVAL (FT): BO'FI'OM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCUNATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 02 MAY 93 M1.33 M1.33 MEMORY 0.0 7987.0 9572.0 0 35.6 43.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 2501-30 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL POLYMER MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 55.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 15000 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0,150 MUD FILTRATE AT MT: 0.210 120.0 MUD CAKE AT MT: 0,000 0.0 0.0 120,0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2,65 HOLE CORRECTION (IN): 9,875 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0,0 0 REMARKS: THE INTERVAL FROM 7987 TO 8035' MD (6456 TO 6497' TVD) WAS LOGGED 11.5 HOURS AFTER DRILLED DUE TO BIT TRIP. $ CN : Arco Alaska Inc WN : P1-21 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 1234567890123456789012345678901234567~123456789012345678.90123456789012345678.90 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 4 * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999,250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 32 128 Sum: 32 128 128 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 32 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod I ATCM MWD 68 I -dB 4 2 ATDC MWD 68 1 -dB 4 3 BDCM MWD 68 1 G/CC 4 4 BDEM MWD 68 1 MINS 4 5 CADE MWD 68 1 MMHO 4 6 CPDE MWD 68 I MMHO 4 7 DCCM MWD 68 I 4 8 DLAM MWD 68 I G/CC 4 9 DPEM MWD 68 I MINS 4 10 DPLMMWD 68 I PU 4 11 DPSMMWD 68 I PU 4 12 DRHMMWD 68 1 G/CC 4 13 DSAMMWD 68 1 G/CC 4 14 GRAMMWD 68 I GAPI 4 15 LPOMMWD 68 1 PU 4 16 NFBMMWD 68 I CPS 4 17 NNBMMWD 68 1 CPS 4 18 NPEMMWD 68 1 MINS 4 19 NPLMMWD 68 I PU 4 20 NPSM MWD 68 1 PU 4 21 NRCM MWD 68 1 RAT 4 22 PDCM MWD 68 I DEG 4 23 PDDC MWD 68 1 DEG 4 24 PDEM MWD 68 1 MINS 4 25 RACM MWD 68 1 OHMM 4 26 RADE MWD 68 1 OHMM 4 27 ROPA MWD 68 I FPHR 4 28 ROPS MWD 68 I FPHR 4 29 RPCM MWD 68 1 OHMM 4 30 RPDE MWD 68 I OHMM 4 31 SPOM MWD 68 1 PU 4 32 TCDM MWD 68 1 DEGF 4 . 128 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 49866O 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length Indicates: 7 FRAMES * DATA RECORD (TYPE# O) 930 BYTES * Total Data Records: 906 Tape File Start Depth = 7987.000000 Tape File End Depth = 9572.000000 Tape File Levet Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 50494 datums Tape Subfile: 4 972 records... Minimum record length: 62 bytes Maximum record length: 930 bytes Tape Subtile 5 is type: US **** FILE HEADER **** MWD .004 1024 LIS COMMENT RECORD(s): 12345678901234567890 ! 23456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate tiles. BIT RUN NO: 5 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9572.0 10955.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): mD DRILLER (Fl'): TOP LOG INTERVAL (FT): BO'I rOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCUNATION (DEC) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 04 MAY ~ M1.33 M1.33 MEMORY 0.0 9572.0 10955.0 0 37.5 42.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 2501-30 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (Fi'): 9.875 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL POLYMER MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 48.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 15000 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.160 MUD FILTRATE AT MT: 0.210 120.0 MUD CAKE AT MT: 0,000 0.0 0.0 120,0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 9.875 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0,0 0 REMARKS: THE INTERVAL FROM 9571 TO 9620' MD (7685 TO 7721' TVD) WAS LOGGED 12 HOURS AFTER DRILLED DUE TO BIT TRIP. $ CN : Arco Alaska Inc WN : P1-21 FN :Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 123456789012345678901234567890123456789012345678.901234567890123456789012345678.90 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 5 * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999,250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator, Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 32 128 Sum: 32 128 128 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 32 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cis Mod 1 ATCM MWD 68 I -dB 4 2 ATDC MWD 68 I -dB 4 3 BDCM MWD 68 1 G/CC 4 4 BDEM MWD 68 1 MINS 4 5 CADE MWD 68 1 MMHO 4 6 CPDE MWD 68 1 MMHO 4 7 DCCM MWD 68 I 4 8 DLAM MWD 68 I G/CC 4 9 DPEM MWD 68 1 MINS 4 10 DPLMMWD 68 1 PU 4 11 DPSMMWD 68 I PU 4 12 DRHM MWD 68 1 G/CC 4 13 DSAMMWD 68 1 G/CC 4 14 GRAMMWD 68 I GAPI 4 15 LPOMMWD 68 I PU 4 16 NFBMMWD 68 1 CPS 4 17 NNBMMWD 68 1 CPS 4 18 NPEM MWD 68 I MINS 4 19 NPLMMWD 68 1 PU 4 20 NPSM MWD 68 1 PU 4 21 NRCM MWD 68 I RAT 4 22 PDCM MWD 68 I DEG 4 23 PDDC MWD 68 1 DEG 4 24 PDEM MWD 68 1 MINS 4 25 RACM MWD 68 1 OHMM 4 26 RADE MWD 68 1 OHMM 4 27 ROPA MWD 68 1 FPHR 4 28 ROPS MWD 68 1 FPHR 4 29 RPCM MWD 68 I OHMM 4 30 RPDE MWD 68 1 OHMM 4 31 SPOM MWD 68 1 PU 4 32 TCDM MWD 68 I DEGF 4 _ 128 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 9866O 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD O'YPE# O) 930 BYTES* Total Data Records: 791 Tape File Start Depth = 9572.0(X)000 Tape File End Depth = 10955.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 56724 datums Tape Subtile: 5 857 records... Minimum record length: 62 bytes Maximum record length: 930 bytes Tape Subtile 6 is type: LIS *"* FILE HEADER **** MWD .005 1024 LIS COMMENT RECORD(s): 12345678,901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 10955.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCUNATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 11513.0 STOP DEPTH 05 MAY 93 M1.33 M1.33 MEMORY 0.0 10955.O 11513.O 0 34.5 36.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 2501-30 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL POLYMER MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S):. 0.0 MUD PH: 0.0 MUD CHLORIDES (PPM): 16750 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.370 MUD FILTRATE AT MT: 0.240 136.0 MUD CAKE AT MT: 0.000 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 9.875 0,0 136.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: THE INTERVAL FROM 10955 TO 11003' MD (8738 TO 8777' TVD WAS LOGGED 18 HOURS AFTER DRILLED DUE TO BIT TRIP AND BOP TEST. THE INTERVAL FROM 11513 TO 11525' MD (9192 TO 9202' TVD WAS NOT LOGGED DUE TO BIT TO SENSOR OFFSETS. GAPS IN DENSITY AND NEUTRON DATA ON RUNS 3 AND 4 ARE DUE TO HIGH ROP. PRUDHOE BAY DRILLING WAS NOT INTERESTED IN GOOD QUALITY POROSITY DATA DURING THIS INTERVAL, THE INTERVAL FROM 11100 TO 11525' MD (88,53 TO 9202' TVD WAS CONTROL DRILLED AT 60 FT/HR FOR A GOOD QUALITY POROSITY LOG. $ CN : Arco Alaska Inc WN : P1-21 ,FN : Pt. Mclntyre COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 123456789012345678901234567890123456789012345678901234567890123456789012345678,90 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 6 * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator, Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 000000 0 1 000 1 Rep Code Count Bytes 68 32 128 Sum: fndun a [F 32 128 128 ] ~.oooooooo ONE DEPTH PER FRAME Tape depth ID: F 32 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ (:;is Mod 1 ATCM MWD 68 1 -dB 4 2 ATDC MWD 68 1 -dB 4 3 BDCM MWD 68 1 G/CC 4 4 BDEM MWD 68 1 MINS 4 5 CADE MWD 68 1 MMHO 4 6 CPDE MWD 68 1 MMHO 4 7 DCCM MWD 68 1 4 8 DLAM MWD 68 1 G/CC 4 9 DPEM MWD 68 1 MINS 4 10 DPLMMWD 68 1 PU 4 11 DPSMMWD 68 1 PU 4 12 DRHMMWD 68 1 G/CC 4 13 DSAMMWD 68 1 G/CC 4 14 GRAMMWD 68 1 GAPI 4 15 LPOMMWD 68 1 PU 4 16 NFBMMWD 68 1 CPS 4 17 NNBMMWD 68 1 CPS 4 18 NPEM MWD 68 1 MINS 4 19 NPLMMWD 68 1 PU 4 20 NPSM MWD 68 1 PU 4 21 NRCM MWD 68 1 RAT 4 22 PDCM MWD 68 1 DEG 4 23 PDDC MWD 68 I DEG 4 24 PDEM MWD 68 1 MINS 4 25 RACM MWD 68 1 OHMM 4 26 RADE MWD 68 1 OHMM 4 27 ROPA MWD 68 1 FPHR 4 28 ROPS MWD 68 1 FPHR 4 29 RPCM MWD 68 1 OHMM 4 30 RPDE MWD 68 1 OHMM 4 31 SPOM MWD 68 1 PU 4 32 TCDM MWD 68 1 DEGF 4 128 498660 71 6 49866O 71 § 498660 71 6 498660 71 6 49866O 71 6 49866O 71 6 4 98660 71 6 49866O 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 49866O 71 6 498660 71 6 49866O 71 6 498660 71 6 498660 71 6 49866O 71 6 49866O 71 6 49866O 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 49866O 71 6 498660 71 6 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# O) 930 BYTES * Total Data Records: 326 Tape File Start Depth = 10955.000000 Tape File End Depth = 11525,000000 Tape File Level Spacing = 0.250000 Tape File Depth Units -- Feet **** FILE TRAILER **** US representation code decoding summary: Rep Code: 68 63560 datums Tape Subtile: 6 405 records... Minimum record length: 62 bytes Maximum record length: 930 bytes Tape Subtile 7 is type: LIS **** TAPE TRAILER **** MWD 93/10/13 1213 01 **** REEL TRAILER **** MWD 93/10/14 1213 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 14 OCT 93 8:06a Elapsed execution time = 2 minutes, 50.5 seconds. SYSTEM RETURN CODE = 0 Tape Subfile I is type: US Tape Subtile 2 is type: LIS DEPTH RHOB FCNT NCNT RP PEF NPHI DRHO RA GR ROP 6873.0000 -999.2500 18,5625 6084,9990 -999.2500 -999.2500 42.0693 -999.2500 -999.2500 -999.2500 -999.2500 6873.5000 2.2311 18.5625 6084.999O -999.2500 2.6314 42.0693 0.1632 -999.2500 6900.0000 2.2956 19.6700 6319.4687 2.5249 2.8927 40.9964 0.0985 3.1695 62.8518 -999.2500 6950.0000 2.2240 21.9325 6334.7158 1.5855 2.3648 36.0586 0.1284 1.6315 51.6215 360.8683 7000.0000 2.4099 24.2180 6300.5244 3.2366 2.9976 32.1286 O. 1745 ' 3.0981 102.0598 81.1545 7050.0000 2.3335 23.4444 6178.5557 2.0476 2.5995 32,4918 0.1789 2.3693 62,5596 257.9471 7100.0000 2.3942 21.9755 6398,8154 2.9564 2.7957 36,3996 O. 1293 3.0436 90.9549 61,61 79 7150,0000 2.1856 23.5086 6354,9111 1,8188 2.2502 33.5048 0.0806 1.7694 56.5687 279.7548 7200.0000 2.2519 23.6408 6368.5020 1.7538 2.3390 33.3940 0.1004 1.7844 49.1764 354.4001 7250.0000 2,2168 24.2646 6321.2764 1,4631 2.3865 32.0731 0.1389 1.5472 53.6815 314.9678 7300.0000 2.2101 25,6449 6373.9766 0.9805 2.1107 30,4266 0.0908 0.9852 23.7082 201,3378 7350.0000 2.41 98 25,2812 6407.0117 3.5193 2,9026 31.0971 0.1140 2.9212 69.9470 56.53,33 DEPTH FCNT RP 7400.0000 25.7750 1.0616 7450.0000 26.1112 1.2844 7500.0000 25.7607 1.6957 7550.0000 23.5777 2.1127 7600.0000 22,2314 3.7513 7650.0000 24.6788 3.0743 7700.0000 24.3029 2.8726 7750.0000 24.6395 3.5051 7800.0000 24.2344 3.0556 7850.0000 26.9264 2.7291 7900.0000 24.7775 1.4313 7950.0000 20.0950 2.1273 RHOB NCNT 2.3062 6376.6016 2.2813 6450.3232 2.3355 6390.5986 2.4391 6413.9111 2.3791 6289.2676 2.3834 6368.9541 2.3590 6404.0391 2.3579 6315.9316 2.3832 6271.2900 2.3949 6436.4648 2.2541 6476.6162 2.1753 6293.9785 PEF NPHI 2.5091 30.2719 2.3085 30.2188 2.5858 30.3617 3.1463 33.6731 3.2433 35.2074 2.8481 31.7364 3.0341 32.4873 2.8254 31.4966 2.9740 31.8332 2.7529 29.1221 2.5228 32.1942 3.3220 39.7146 DRHO RA 0.0818 1.1073 0.0965 1.2035 0.0680 1.7732 0.1261 2.4022 0.1422 3.9022 0.1104 2.1283 0.1640 2.6877 0.1259 3.4745 0.1699 2.7215 0.0704 2.4135 0.1962 1.6810 0.0566 2.1127 GR ROP 35.6693 130.1602 39.2698 248.9861 58.5899 162.9448 88.7431 90.4163 101.2616 56.9654 89.0247 65.1722 75.5130 50.8925 81.6716 31.2496 82.8392 44.7810 77,7852 44.5910 49.2778 54.1849 63.6817 57.8334 DEPTH FCNT RP RHOB NCNT PEF NPHI DRHO RA GR ROP 8000.0000 24.7512 2.0005 2,3277 6418.7002 2.9816 31.9094 0.0526 2.1663 59,2807 36.2844 8050.0000 27.4060 4,8557 2.2393 6431.2305 2,7001 28.5217 0.0382 2.7606 36.6337 59.5389 8100.0000 26.1805 1.2133 2.2532 6369.2070 2.7677 29.7040 0.0469 1.3943 58.8683 255.6875 8150,0000 29,0146 2.0200 2.2884 6441,3643 2.8302 26.7770 0.0697 2,4412 65,1850 143.7914 8200,0000 28.7164 4.1820 2.4572 6538,6650 3.1900 27.5631 0.0308 5.3802 89,2982 55.5748 8250.0000 28.8901 2,8714 2.3443 6560.3516 3.4239 27,4779 0,0726 3.5781 58,6475 116.5684 6300,0000 29.8257 2.6187 2.3751 6498.7324 3.0875 26,2069 0.0442 2.7057 64.5640 81.4291 8350.0000 31,7465 5.2436 2.3968 6569.9687 3.2068 24.6805 0.0597 6.1904 98.2437 41.5960 8400,0000 32.5080 3,6718 2.4227 6539.6504 3,3690 23.8668 0.0423 4.3553 63.1507 99.2544 6450,0000 26.4087 1,3848 2.1860 6441,5674 2.2461 29.7915 0.0288 1.3635 26,4506 412.2275 8500,0000 34.1646 3.3504 2.4654 6546,2393 3.3308 22.5085 0,0135 4.1362 67.5043 123.0795 6550.0000 28.2103 3.6808 2.4008 6367.3320 3,1938 27.2889 0.0834 4.6261 80.0559 139.1885 DEPTH FCNT RP 8600,0000 27.0947 4.5115 8650.0000 34.2712 4.5154 8700.0000 29.2739 4.8267 8750.0000 26.4527 2.3717 8800.0000 26.4980 2,3663 8850.0000 24.3500 2.9652 8900.0000 29.5888 2.9081 8950.0000 27.5862 2.2577 9000.0000 30.8668 2.3345 9050.0000 25.4706 4.8782 9100.0000 24.3973 1.9310 9150.0000 24.1309 2.9101 RHOB NCNT 2.4802 6489.0908 2.4859 6570.4297 2.4580 6526.3125 2.4859 6489,4238 2.4213 6442.6240 2.4590 6509.1357 2.4394 6443,7900 2.4491 6515.2207 2.4171 6444.7061 2.4679 6450.3311 2.4816 2.5539 6445.5879 PEF NPHI 3.8307 29.1649 3.5344 22.5243 3.7551 26.9064 3.5411 29.6843 3.5600 33.0152 3.6394 26.1913 3.5129 28.7293 3.4303 24.9384 3.5493 31.0719 3.4384 32.5770 3.7254 32.9866 DRHO RA -0.0264 6.0402 0.0310 6.1484 0.1319 2.6369 0.0552 2.7714 0.1059 3.4528 -0.0074 3.4694 0.0550 1.9237 -0.0150 2.6617 0.0069 6.1475 0.1181 2.0384 0.1574 3.1354 GR ROP 101.8694 96.9078 114.0389 96.6605 110.3713 57.3014 77.1240 70.4807 90.4427 119.7013 108.9512 112.0469 115,0078 88.3426 119.7895 85.3773 111.2169 93,9893 121.0885 131.9204 115.5248 84.8486 132.3187 82.1991 DEPTH FCNT RP 9200.0000 27.7621 2,2089 9250,0000 28.3963 2.5367 9300.0000 24.8031 2,6735 9350.0000 25.5755 2.8378 9400,0000 25.0136 3.0820 9450,0000 27.6973 3.1181 9500.0000 26.2171 2,9510 9550,0000 23.4773 1.9542 9600.0000 27.3682 2.6645 9650,0000 28,5251 2.7528 9700.0000 27.5033 2.6807 9750.0000 28,9266 2.9430 RHOB NCNT 2.4360 6551.8145 2,4031 6361,3604 2.3747 6420.7344 2.3739 6423.2793 2,4904 6617,6611 2.3743 6513,2441 2.4020 6522.6641 2.2997 6218.4707 2.4176 6394.0537 2.4119 6487,2881 2.4161 6498.3457 2.4276 6427,3066 PEF NPHI 3.5594 28.7048 3.4615 27.0558 3.5861 31.8459 3.3112 30,7838 3,7922 32.6331 3.4150 28.5894 3.4035 30.4604 5.1123 32.6759 3.6744 28,3796 3.5846 27,5253 3.5347 28,7428 3.5907 26,8032 DRHO RA -0,0139 2.3960 -0.0038 2.8183 0.0744 3.2041 0.0155 3.3474 0,1287 3,4986 0.0353 3.3517 0.0061 3.2589 0.0801 2.3361 0,0308 3.0660 0,0184 3.1591 0.0304 3.1869 0.0097 3,4965 GR ROP 114.9798 72.3842 110.9462 52.3648 101.4314 116,8023 110.8029 106.9474 98,8251 75.7699 112,0176 77.7393 107.9529 78,0320 107.7247 58.5164 103.4684 37.9601 102.4756 85.6484 103,4107 57.4395 107,4677 53,4199 DEPTH FCNT RP 9800.0000 30.9468 2.5296 9850.0000 23.9437 2.4993 9900.0000 28.1042 2.1212 9950.0000 28.9887 3.4006 10000.0000 28.0976 2.1887 10050.0000 25.0315 2.4699 1O100.0000 31.1293 3.0002 1O150.00O0 28.9969 3.1809 10200.0000 25.7898 2.9497 10250.0000 29.9956 2.7316 10300.0000 31.9617 2.8658 10350.0000 27.1870 2.9506 RHOB NCNT 2.4386 6407.8506 2.4720 6410.9961 2.4250 6587.3330 2.4400 6538.3027 2.4322 6449.2559 2.4571 6586.0098 2.4685 6561.6074 2.4799 65O4.5908 2.5238 6597.6338 2.5526 6627.2773 2.5122 6346.8066 PEF NPHI 3.7550 24.6958 3.5186 33.1094 3.4148 28.5064 3.4798 27.2664 3.4471 27.8156 3.7487 32.4317 4.0763 25.2174 3.6805 27.0971 3.6491 31.4264 3.6410 26.3916 3.6360 24.7366 3.7387 28.3547 DRHO RA 0.0106 2.9363 0.0803 2.7064 0.0025 2.3893 0.0247 3.7780 0.0033 2.5326 0.0098 2.8487 0.0257 3.2135 0.0243 3.4601 0.0938 3.2389 0.0354 3.4807 0.1609 3.4052 0.0227 3.4851 GR ROP 106.3425 59.3084 123.8766 93.8374 114,2343 206.0325 109.4491 200.7356 105.8407 1 43.6729 106.9230 175.8640 104.8149 144.4994 109.2733 133.8800 128.2818 54.8371 100.5217 72.1448 95.0845 112.5929 134.2162 102.6652 DEPTH FCNT RP 10400.0000 32.2866 2.4649 10450,0000 29,7970 3,2021 10500.0000 33.0679 5.0361 10550,0000 28.5548 2,6878 10600.0000 25.6105 2.5573 10650.0000 23.8882 1.7691 10700.0000 29.8075 6.2245 10750.0000 27.7798 2.7924 10800.0000 26,2684 2,0178 10850.0000 23.3491 2,2081 10900.0000 22.3143 2.0436 10950.0000 14.7022 1.0593 RHOB NCNT 2.4839 6569.0020 2.5548 6455,1641 2.4893 6675,5820 2.4496 6427.3613 2,4030 6419,8223 2.4009 6433.5225 2.4092 6355.6562 2,4403 6451.5234 2.4377 6471,9033 2.5074 6243,6221 2.4046 6244.7959 1,7006 5890.7812 PEF NPHI 3,4917 24,1896 3,7157 26,0330 3.8462 23.9662 4.0050 27.2032 3.5728 30.7182 3,7393 ~.2943 3.9615 25.5614 3,8778 28.1882 3,8278 30,1286 5.9128 33.0279 4,0514 34.7760 7.5048 57.2163 DRHO RA 0.0119 2.9743 0.0423 3,8235 0,0176 6,5164 0.0296 3.1790 0.0458 2.6174 0.0103 2,5993 0.0273 5.2096 -0.0023 2.6260 0,0276 1.9368 -0.0145 1,8683 0.028 2.0126 0,0548 1.2923 GR ROP 123.8252 148.6882 t15.1357 102.5092 135,4066 141.1178 1 64.8970 98.7838 125.6551 94.3773 152,5540 53.2534 174.1472 48,4240 180.5916 65,2173 214.6958 34.5118 180.4404 42.5862 105.2200 54,6583 DEPTH FCNT RP 11000.0000 22.7199 1.9708 11050.0000 39.3239 5.9445 11100.0000 28.3393 7.6693 11150.0000 28.8640 17.6879 11200.0000 34.8427 36.9968 11250.0000 34.7040 25.1808 11300.0000 32.2843 13.9543 11350.0000 31.9039 8.4904 11400.0000 31.7027 4.8367 11450.0000 40.0179 3.1373' 11500.0000 -999.2500 -999.2500 11502.0000 -999.2500 -999.2500 RHOB NCNT 2.4215 6290:6348 2.4810 6700.5244 2. ~.. ~.~. 6725.7480 2.4857 6552.1318 2.3951 6700.9863 2.5728 6754.8242 2.3824 6677.1523 2.5223 6593.6045 2.4286 6662.0322 2.4794 6690.8965 -999.2500 -999.2500 -999.2500 -999.2500 PEF NPHI 4.0207 -,~-34.3540 3.5887 19.4356 7.5499 28.6876 6.2124 27.4671 4.2365 22.6104 5.6134 22.9410 3.1150 24.6826 4.8817 24.6412 4.4067 25.1274 4.2711 18.9656 -999.2500 -999.2500 - -999.2500 -999.2500 DRHO RA 0.0868 2.1149 0.0561 10.1463 -0.0348 13.7590 -0.0423 -999.2500 -0.0432 -999.2500 -0.0231 -999.2500 -0.0867 -999.2500 0.0001 18.9841 0.0800 8.2035 O.0738 3.7295 -999.2500 -999.2500 -999.2500 -999.2500 GR ROP 138.1564 24.2133 96.8620 21.4303 76.4368 47.0598 63.9716 48.6734 49.0829 51.3401 61.8350 38.5205 65.9235 ~.0965 67.7300 44.2986 50.3414 46.9501 -999.2500 42.5827 -999.2500 39.3775 Tape File Start Depth = 6873,000000 Tape File End Depth = t 1502.000000 Tape File Level Spacing = 0,500000 Tape File Depth Units = Feet Tape Subtile 3 is type: US DEPTH ATCM ATDC BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 6894,0000 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 . -999,2500 -999,2500 -999,2500 -999,2500 27.4648 -999,2500 -999,2500 1,9629 -999,2500 37,5786 18,5625 6084,9990 -999,2500 34,3832 38,3153 324,2055 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 42,0693 -999,2500 6894,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 27,5106 -999,2500 -999,2500 1,9596 -999,2500 37.5786 18,5625 6084,9990 -999,2500 34,3832 38,3153 324,2055 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 42,0693 -999,2500 6900,0000 -999,2500 -999,2500 2,2711 -999,2500 -999,2500 -999,2500 -999,2500 2,1237 2,6495 25,6665 22,9635 0,1473 2,0255 98,6314 37,0649 18,8683 6124,6416 -999,2500 33,6697 37,5928 321,0298 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 41,5382 -999,2500 6950,0000 1,0848 1,1190 2,2494 -999,2500 303,1840 99,4380 76,6180 2,1192 2,3994 26,9328 24,2758 O, 1303 2,0324 50,1698 8,6820 57,7994 6710,9766 34,0000 4.6001 7,2024 114,8308 6,5330 6,3016 16,3333 3,4171 3,2983 44,9210 19,7821 9,4892 10.0565 11,2651 90,0500 7000,0000 1,0980 1,1567 2,2210 40,0000 315.4821 335.9391 133,9493 2,0539 2,3634 28.5953 25.9988 O. 1626 1.9455 70.1678 21,2654 31.1250 6492,9980 43,0000 14,4019 17,6597 206,3157 14,3472 14,0493 24,7000 3,3685 3,1698 212,2885 268,7881 2,8675 2,9767 24,9131 89,8250 DEPTH CADE DPLM LPOM NPSM RACM RPDE ATCM CPDE DPSM NFBM NRCM RADE SPOM ATDC DCCM DRHM NNBM PDCM ROPA TCDM BDCM DLAM DSAM NPEM PDDC ROPS BDEM DPEM NPLM ~'i ~- : .: PDEM RPCM 7050.0000 338.4500 19.3872 29.9465 27.7856 3.1385 2.5588 1.1647 390.8141 16.4558 22.7928 272.1798 2.9546 34.1184 1.2258 143.7909 0.1981 6272.7285 15.7029 126.0017 90.6687 2.3785 2.1690 2.0369 43.0000 15.4017 1 40.8504 38.0000 2.5455 90.6688 24.0900 28.3100 2.4710 7100.0000 359.1661 28.2304 37.7402 38.6O82 2.9458 2.5410 1.2272 393.5490 25.6206 19.4943 325.1932 2.7842 42.2361 1.2867 144.2386 0.1792 6403.6387 15.7680 205.7877 92.5700 2.2273 2.0480 1.9286 35.9091 15.4666 253.1346 34.0000 2.3566 77.1280 34.6785 32.7389 2.4549 7150.0000 553.8833 28.1166 27.1793 24.3699 1.8796 1.7591 1.7536 568.4800 25.5027 25.0029 251.4018 1.8054 31.2027 1.8104 171.6873 0.0972 6,331.0898 19.5425 341.7829 95.4500 2.2292 2.1320 2.0672 28.0000 19.2254 413,4291 26.0000 2.3089 54.3549 20.8072 24.3167 1.7067 7200.0000 545.3447 29.0402 30.2487 28.1960 1.6O73 1.5049 1.9750 664.4874 26.4599 22.7438 274.4078 1.5496 34.4357 2.0318 184.8109 0.0986 6307.4004 21.3565 336.3727 98.8000 2.2134 2.1148 2.0491 13.0000 21.0382 332.6569 11.0000 2.4177 41.5334 24.4878 8.9417 1.4647 7250.0000 710.2029 29.0623 28.2730 25.6284 1.4577 1.3469 2.1244 742.4680 26.4828 24.1262 259.6813 1.4080 32.3571 2.1814 194.9341 0.1326 6334.7822 22.7331 342.5417 97.5261 2.2130 2.0805 1.9921 26.7500 22.4133 344.3439 24.0000 2.3112 45.7065 22.0092 19.9167 1.3115 DEPTH CADE DPLM LPOM NPSM RACM RPDE 7300.0000 676.1737 26.6446 26.7092 23.6938 1.5339 1.3571 7350.0000 774.4908 26.8524 28.0506 25.3482 1.3334 1.2782 7400.0000 271.9835 16.3057 29.4873 27.2099 3.9205 3.8766 7450.0000 664.3584 17.7437 25.7607 22.5626 1.5538 1.8673 7500.0000 399.6198 21.3688 30.5861 28.6308 2.5975 4.5335 ATCM CPDE DPSM NFBM NRCM RADE SPOM 2.O454 736.89O0 23.9771 25.6153 247.8242 1.4789 30.7057 2.2684 782.3724 24.1925 24.5727 258.0037 1.2912 32.1226 0.96,53 257.9561 13.2623 23.0363 268.7758 3.6767 33.6357 2.0262 535.5378 14.7526 26.0953 240.5847 1.5052 29.7013 1.3595 220.5824 18.5095 22.3371 276.8828 2.5024 34.7897 ATDC DCCM DRHM NNBM PDCM ROPA TCDM 2.1037 194.2698 0.0812 6418.7031 22.6420 263.6929 98.2786 2.3244 199.8698 0.1135 6410.3525 23.4091 180.1216 100.1375 1.0212 118.3994 0.0471 6256.4385 12.2063 68.1256 101.9750 2.0763 168.1042 0.0737 6347.9492 18.8778 54.7893 104.0000 1.4025 110.1157 0.0827 6253.5459 11.0686 106.5805 105.0125 BDCM DLAM DSAM NPEM PDDC ROPS 2.2544 2.1669 2.1127 30.0000 22.3181 3O5.1758 2.2508 2.1536 2.0779 73.0000 23.0885 180.0159 2.4312 2.3641 2.3527 47.6000 11.9219 59.0631 2.4056 2.3329 2.2838 52.0000 18.5678 42.8207 2.3446 2.2817 2.2266 80.0000 10.7913 114.1886 BDEM DPEM GRAM NPLM PDEM RPCM 24.0000 2.2427 31.3020 20.1511 17.7500 1.3208 70.0000 2.3120 36.6410 21.7396 52.0167 1.2454 39.8750 3.2335 74.5065 23.5356 33.2667 3.7204 49.0000 2.9240 63.3318 19.0679 35.0583 1.8282 72.0000 2.5554 74.4141 24.9078 32.4333 4.3396 DEPTH CADE DPLM LPOM NPSM RACM RPDE ATCM CPDE DPSM NFBM NRCM RADE SPOM ATDC DCCM DRHM NNBM PDCM ROPA TCDM BDCM DLAM DSAM NPEM PDDC ROPS BDEM DPEM GRAM NPLM PDEM RPCM 7550,0000 149.9478 15.4053 21.6223 18,0214 7.1940 13,1081 0,5588 76.2885 12.3292 30.4841 209,0157 6.6690 25.2950 0,6013 68,1192 0,2082 6442,5205 5.4195 30.6592 106.9250 2.4466 2.3235 2.1847 117.0000 5.2045 29.7805 107.0000 2.8945 66.4400 14.7446 88.2500 12.2976 7600,0000 589.6089 22.7511 29.2508 26,8786 1.7603 1,7977 1.8438 556.2799 19,9420 23.4821 267,0142 1.6960 33,3869 1.8984 169,9183 0,1120 6339.7920 19,2993 142.4985 109,0062 2.3210 2.2060 2.1313 127,0000 18,9842 147.6618 117.0000 2.7704 62.1681 23.2140 78.4667 1.7439 7650.0000 485.6415 19.2698 27,6839 24,8898 2.1505 2,0830 1,5797 480.0678 16,3341 24.6815 255.2304 2.0591 31.7357 1.6359 158,4464 0.0821 6364.3701 17.7214 87.4468 110.4125 2.3805 2,2697 2.2150 91.0000 17.4129 108.2934 84.0000 2.9646 64.6675 21.2990 70.1167 2.0172 7700.0000 504.9527 23,8741 25.8785 22,7012 2.0715 1.7532 1.6268 570.3710 21.1058 26.1199 241.4847 1.9804 29.8261 1,6861 171.9546 0.0866 6377,7002 19.5792 112.0980 113.1125 2,3018 2,2017 2,1440 98.0000 19.2626 110,7464 87,0000 2.5400 50.8048 19.2005 64.8000 1.7012 7750.0000 405,6085 21,3368 26,3547 23.2671 2.5910 2.4451 1,3623 408.9843 18.4761 25.5557 245.1209 2,4654 30.3305 1.4193 148.9017 0.1449 6333.9102 16.1315 58.5164 114.5750 2.3451 2.2031 2,1065 100,0000 15.8265 67,1668 91.0000 2.8178 74.7983 19.7422 73.9167 2.3627 DEPTH ATCM ATDC BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 7800.0000 2.1731 2.2299 2.2882 97.00(X) 731.7305 769.9725 198.3804 2.1889 2.4589 24.6647 21.9253 0.0920 2.1276 52.5875 28.2099 24.3450 6380.5625 105.0000 21.9326 25.5487 259.2060 23.2052 22.8806 77.2167 1.4136 1.3668 56.3651 36.5923 1.2649 1.2987 32.2906 116.2625 7850.0000 1.7186 1.7761 2.3078 93.00(X) 540.1718 562.8630 170.8624 2.1964 2,5292 23.5228 20.7418 0.1209 2.1158 60.45(X) 26.1305 25.6474 6312.2529 100.0000 19.4862 22.9997 243.4099 19.4291 19.1162 65.9&33 1.9295 1.8513 78.2316 82.9481 1.7239 1.7766 30.0931 117.1625 7900.0000 1.3190 1.3718 2.3204 291.0000 388.6893 331.0237 133.0334 2.1602 3.3954 22.7864 19.9786 0.1525 2.0585 84.8373 33.0587 20.8834 6219.8076 304.0000 28.1676 31.9851 294.5590 14.2210 13.9247 246.0000 2.6966 2.5727 13.4388 12.7157 2.9092 3.0209 37.3765 118.3250 7950.0000 1.1263 1.1801 2.3673 115.0000 323.3376 284.8212 123.9406 2.1957 3.3412 20.0384 17.1307 0.1717 2.0813 82.6126 27.6292 25.0096 6443.7109 128.0000 21.2336 24.8218 254.8155 12.9687 12.6800 - 94.6167 3.2674 3.0927 39.4080 41.0801 3.3774 3.5110 31.6779 111.5375 7987.0000 1.8365 1.8951 2.2234 922.0000 588.4216 641.8535 181.8407 2.2145 2.6821 28.4575 25.8560 0.0089 2.2086 53.2009 26.7971 25.9375 6517.0000 924.0000 20.2532 23.8003 248.4940 20.9364 20.6183 -999.2500 1.7697 1.6995 53.9720 64.4342 1.5148 1.5580 30.7987 113.4500 Tape File Start Depth = 6894.000000 Tape File End Depth = 7987.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 4 is type: LJS DEPTH ATCM ATDC BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 7987.0000 1.8365 1.8951 2.2234 922.0000 588.4216 641.6535 181.8407 2.2145 2.6821 28.4575 25.6560 0.0089 2.2086 53.2009 26.7971 25.9375 6517.0000 924.0000 20.2532 23.8003 248.4940 20.9384 20.6183 -999.2500 1.7697 1.6995 53.9720 64.4342 1.51 48 1.5580 30.7987 113.4500 7987.2500 1.8554 1.9140 2.2126 922.0000 596.1810 649.6809 182.8740 2.2127 2.6609 29.0891 26.5105 -0.0001 2.2128 64.3298 26.7966 25.9379 65 16.9932 924.0000 20.2526 23.7997 248.4900 21.0790 20.7625 -999.2500 1.7458 1.6773 53.9720 57.4594 1.4971 1.5392 30.7981 113.4500 8000.0000 1.8265 1.8898 2.2244 911.0000 586.2505 753.5629 196.3067 2.1820 2.61 64 28.3991 25.7954 0.0388 2.1562 39.3110 20.0923 32.2182 64,33.3311 921.0000 13.3076 16.5028 197.4834 22.9211 22.5978 -999.2500 1.7823 1.7058 70.9765 98.8980 1.2926 1.3270 23.6561 113.9000 8050.0000 1.3369 1.3997 2.4189 33.0000 398.7631 492.7643 160.3716 2.3760 3.5635 17.0204 14.0030 0.0431 2.3467 72.4287 24.2085 27.7807 6408.3057 39.4546 17.4258 20.8387 228.7133 17.9864 17.6774 27.41 63 2.6520 2.5078 198.8864 244.1406 1.9670 2.0294 28.0532 98.5719 8100.0000 2.6486 2.7056 2.2028 55.0000 957.0607 1015.6716 226.5177 2.1648 2.3508 29.6637 27.1060 0.0372 2.1399 41.7137 26.8295 25.1 402 6322.9365 57.0000 20.2909 23.8397 248.7408 27.0507 26.7199 41.7320 1.0757 1.0449 188.0599 154.0819 0.9620 0.9846 30.8330 100.7375 DEPTH CADE DPLM IPOM NPSM RACM RPDE 8150.0000 191.2551 16.9432 26.2391 23.1290 5.7218 4.8264 8200.0000 159.4458 16.2490 22.7367 19.1809 7.0470 4.5928 8250.0000 172.7628 22.0961 26.4817 23.4195 6.4761 4.0195 8300.0000 331.6729 22.0654 24.7653 21.4112 3.2043 2.6622 8350.0000 183.0576 21.1372 23.2383 19.7178 6.0387 4.3424 ATCM CPDE DPSM NFBM NRCM RADE SPOM 0.6909 207.1942 13.9230 25.9882 244.2391 5.2286 30.2081 0.5697 217.7299 13.2035 29.0357 217.4796 6.2717 26.4854 0.6165 248.7887 19.2632 26.1175 248.0902 5.7883 30.4650 1.1447 375.6351 19.2314 26.8749 232.9715 3.015O 28.6450 0.6577 230.2875 18.2695 29.0037 221.3018 5.4628 27.0202 ATDC DCCM DRHM NNBM PDCM ROPA TCDM 0.7507 106.9327 0.0914 6417.9199 10.6312 25.3887 103.3250 0.6362 109.4270 0.0168 6384.9043 10.9731 36.6824 106.7000 0.6847 116.3655 0.0407 6498.7441 11.9284 122.0467 109.8950 1.2052 141.0993 0.1307 6330.7187 15.3312 59.7856 111.3125 0.7216 112.2927 0.0023 6489.9727 11.3663 53.3686 112.8875 BDCM DLAM DSAM NPEM PDDC ROPS 2.4203 2.3557 2.2948 101.0000 10.3573 29.7732 2.4321 2.3850 2.3739 101.0000 10.6946 43.2181 2.3322 2.2914 2.2643 70.0000 11.6456 144.3911 2.3327 2.2034 2.1162 101.0000 15.0314 47.8903 2.3486 2.3145 2.3129 81.0000 11.0866 67.8168 BDEM DPEM GRAM NPLM PDEM RPCM 93.0000 3.6723 106.8638 19.6100 50.7167 4.6194 97.0000 3.7209 112.1569 15.8447 80.5000 4.3980 67.0000 3.2208 55.4799 19.8882 40.7667 3.8582 68.0000 3.2145 70.7352 17.9680 58.8167 2.5708 77.0000 3.0043 68.5730 16.3550 59.4,,333 4.1627 DEPTH CADE DPLM LPOM NPSM RACM RPDE ATCM CPDE DPSM NFBM NRCM RADE SPOM ATDC DCCM DRHM NNBM PDCM ROPA TCDM BDCM DLAM DSAM NPEM PDDC ROPS BDEM DPEM GRAM NPLM PDEM RPCM 8400.0000 300.2233 17.8288 22.3705 18.8129 3.6040 3.2888 1.0519 304.0626 14.8408 30,0500 214,6934 3.3309 26,0945 1.1095 127.8940 0,0258 6513.4004 13.4982 341.6201 111.4250 2,4051 2.3793 2,3638 32.4O0O 13.2062 121,4127 38.0909 3.2740 89.9266 15,4965 24.5333 3.1609 8450.0000 195.2296 14,4809 19.4859 15.9233 5.6050 4.5805 0.7040 218.3171 11.3711 33.8028 192,9450 5,1222 23.0050 0.7646 109.5608 0.0293 6594.6299 10.9914 68.5931 113,6750 2.4624 2.4240 2.4045 40.0000 10.7131 64,0735 37,0000 3.3391 93,3962 12.7605 29,9000 4.3865 8500.0000 309.9790 18.3696 26,8047 23.8098 3.4383 2.8728 1.0791 348,0880 15.4012 26.1134 248,5520 3.2260 30.8067 1,1395 136.1434 0.1187 6562.7285 14,6485 150.7056 114.2375 2.3959 2.2911 2.2120 40,0000 14,3512 151.8670 37.0000 3,4147 68.9628 20.2621 27,3667 2.7712 8550.0000 191,3459 12.2570 20.4134 16.8146 5.7528 4.2350 0.6875 236.1270 9.0663 31.9268 199.8943 5.2261 24.0005 0.7510 113.5987 0,0843 6453.3662 11.5456 63.5341 116.3750 2.5004 2.4045 2.3483 53.0000 11.2651 73.1186 48,0000 3.5769 93,5083 13.6024 37.2667 4,0617 8600.0000 1 65.05~37 15.0374 22.3821 18.8009 6.7173 5.3747 0.5959 186,0558 11.9478 30.1750 214.7813 6.0585 26.1069 0.6568 101.7619 0.1089 6553.1172 9.9237 132.5026 116.7125 2,4529 2.3542 2.2814 50.0000 9.6552 171.7024 45.0000 3.2696 102.3963 15.4896 35,6167 5.1351 DEPTH CADE DPLM LPOM NPSM FIAOM RPDE 8650.0000 189.5041 17.5897 20.1054 16.5153 5.8232 4.1254 8700.0000 155.4004 12.5070 24.0826 20.6432 7.2207 5.0409 8750.0000 219.1057 16.0754 28.2139 25.5537 4.9796 3.6304 8800.0000 338.2108 14.7578 28.5913 26.0432 3.1399 2.6104 8850.0000 338.8138 18.0287 26.8626 23.8798 3.1356 2.5624 ATCM CPDE DPSM NFBM NRCM RADE SPOM 0.6799 242.4013 14.5929 32.7390 197.5811 5.2769 23.6701 0.5568 198.3769 9.3255 28.2598 227.7508 6.4350 27.9193 0.7830 275.4548 13.0236 24.4642 259.2358 4.5640 32.2948 1.1642 383.0845 11.6581 23.2701 262.0768 2.9567 32.6926 1.1655 390.2532 15.0479 25.2838 248.9923 2.9515 30.8679 ATDC DCCM DRHM NNBM PDCM ROPA TCDM 0.7445 114.9947 0.0953 6540.5625 11.7373 106.2621 118.1750 0.6212 104.8091 0.0196 6507.7754 10.3404 58.6090 115.8125 0.8469 122.0431 0.1063 5412.5303 12.7065 70.8126 114.4825 1.2247 142.4153 0.0979 6165.1455 15.5125 107.2172 118.2031 1.2265 143.6581 0.0976 6365.5000 15.6837 87.6660 120.1625 BDCM DLAM DSAM NPEM PDDC ROPS 2.4092 2.3075 2.2440 75.0000 11.4549 114.4682 2.4961 2.4632 2.4501 61.0000 10.0687 41.4997 2.4351 2.3393 2.2684 61.0000 12.4176 86.1948 2.4576 2.3502 2.2849 48.6364 15.2111 100.6698 2.4017 2.2957 2.2300 48.0000 15.3824 84.3095 BDEM DPEM GRAM NPLM PDEM RPCM 69.0000 3.5217 89.6082 13.3195 54.6667 3.9578 56.0000 3.7952 110.2449 17.2358 43.3000 4.8213 58.00(X) 3.5740 99.5831 21.9374 47.6333 3.4893 41.0000 3.5856 102.4064 22.4094 30.7000 2.5213 44.0000 3.6859 108.5044 20.3294 33.6500 2.4758 DEPTH CADE DPLM LPOM NPSM RACM RPDE ATCM CPDE DPSM NFBM NRCM RADE SPOM ATDC DCCM DRHM NNBM PDCM ROPA TCDM BDCM DLAM DSAM NPEM PDDC ROPS BDEM DPEM GRAM NPLM PDEM RPCM 8900.0000 284,7667 16,5442 32,7575 31,5704 3.7725 2,7899 0.9975 358.4356 13.5094 21.2177 292.4547 3.5116 37.O622 1,0614 138.O242 -0.0295 6274,2432 14.9076 110,7483 121.4094 2,4271 2,4408 2.4703 68,0000 14.6097 118.1326 65.0000 3.4514 109.3842 27.7634 31.3000 2.6925 8950.0000 314.5549 16.1721 22.5558 18.9894 3.3857 2.8400 1.0932 352.1091 13.1238 29.2772 216,1020 3.1791 26,2923 1.1535 136.8935 -0.0005 6397.2197 14.7518 116.5013 121.7750 2,4335 2.4345 2.4350 69.0000 14,4521 90,8688 66.0000 3.5636 114.8766 15.6629 55.7333 2.7394 9000.0000 280.4755 18.1490 21.9215 18.3281 3.8164 3.2190 0.9877 310.6562 15.1726 30.8429 211.28,33 3.5654 25.6148 1.0478 129.0785 0.1143 6589.0781 13.6752 90.7777 117.9500 2.3997 2.3068 2.2306 57.0000 13.3827 87.2588 51.0000 3.5276 111.5599 15.0354 30.9667 3.1001 9050.0000 322.6918 14.1635 24.1801 20.7518 3.3054 2.5367 1.1154 394.2196 11.0422 28.2011 228.4959 3.0989 28.0230 1.1782 144.3427 0.0030 6515.5156 15.7779 102.2675 118.0625 2.4678 2.4729 2.4709 63.0000 15.4764 122.2029 58.0000 3.7226 117.5955 17.3393 48.2667 2.4512 9100.0000 211.8099 13.9713 25.9377 22.7711 5.1538 3.9179 0.7593 255.2365 10.8430 25.8654 241.9370 4.7212 29.8888 0.8220 117.7915 0.0173 6327.3936 12.1217 111.6287 118.6500 2.4711 2.~5 2.4330 61.0000 11.8358 144.3911 55.0000 3.3983 111.5000 19.2674 35.8000 3.7612 DEPTH CADE DPLM LPOM NPSM RACM RPDE 9150.0000 438.0010 17.9236 28.1985 25.5343 2.3948 2.2222 9200.0000 389.1217 14.6569 24.3611 20.9543 2.7108 2.3629 925O.0000 357.4207 15.8873 23.9696 20.5178 2.9658 2.4312 9300.0000 330.4232 17.7311 26.8938 23.9178 3.2141 2.7410 9350.0000 298.6107 18.3176 24.8402 21.4965 3.5744 3.0068 ATCM CPDE DPSM NFBM NRCM RADE SPOM 1.4509 450.0121 14.9390 23.8887 259.1200 2.2831 32.2786 1.3133 423.2086 11.5535 28.0054 229.8798 2.5699 28.2154 1.2204 411.3214 12.8287 28.0600 226.8868 2.7978 27.7990 1.1418 364.8314 14.7395 25.6913 249.2302 3.0264 30.9009 1.0443 332.5808 15.3474 27.6053 233.5446 3.3488 28.7245 ATDC DCCM DRHM NNBM PDCM ROPA TCDM 1.5083 153.6380 0.0933 6268.8848 17.0584 82.1808 118.8500 1.3725 149.2706 0.0101 6509.4707 16.4569 85.0819 120.4250 1.2813 147.2589 -0.0331 6437.2422 16.1797 101.4494 120.6500 1.2015 139.1774 -0.0026 6474.2783 15.0665 69.1720 118.5125 1.1046 1 33.2682 0.0669 6519.0166 14.2524 69.0312 119.6375 BDCM DLAM DSAM NPEM PDDC ROPS 2.4035 2.3163 2.2544 62.0000 16.7526 83.2298 2.4594 2.4658 2.4591 75.0000 16.1501 87.1931 2.4383 2.4261 2.4592 62.0000 15.8767 126.2796 2.4068 2.4059 2.4084 57.0000 14.7677 68.9046 2.3968 2.3221 2.2775 47.OO00 13.9568 65.0859 BDEM DPEM GRAM NPLM PDEM RPCM 57.0000 3.7276 108.4980 21.9187 44.2833 2.1512 71.0000 3.7430 118.6930 17.5323 55.5996 2.2849 57.0000 3.3528 115.0470 17.1163 43.4324 2.3507 53.0000 3.4,5,33 104.8675 2O.3658 40.4162 2.6459 43.0000 3.5942 106.6016 18.0494 32.0495 2.8984 DEPTH ATCM ATDC BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM II=OM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 9400.0000 1.0347 1.0961 2.4502 57.0000 295.8722 342.9901 135.2010 2.3181 3.4252 15.1953 12.1115 0.1283 2.2326 101.8863 26.6567 25.7164 64,.33.6406 62.0000 20.0902 23.6303 247.4241 14.5187 14.2224 42.8500 3.6137 3.3798 76.1504 78.7570 2.8120 2.9155 30.6501 120.6500 9450.0000 1.0263 1.0861 2.4475 58.0000 292.6429 321.2871 131.1602 2.2889 3.6074 15.3513 12.2732 0.1599 2.1823 107.0664 27.3237 25.2749 6452.8711 63.0000 20.8708 24.4440 252.4986 13.9620 13.6658 43.1667 3.6486 3.4171 78.8784 91.8731 2.9973 3.1125 31.3553 123.3500 9500.0000 0.9664 1.0270 2.4067 66.0000 273.8606 307.4889 128.4969 2.4089 3.2618 17.7358 14.7~d~. -0.0147 2.4230 109.3839 28.3190 24.6627 6484.3262 76.0000 22.0652 25.6865 260.0282 13.5951 13.3005 51.1667 3.9147 3.6515 69.4781 60.0658 3.1297 3.2521 32.4057 123.9125 9550.0000 1.2898 1.3503 2.3810 72.0000 381.2557 433.7858 151.0346 2.2814 3.3987 19.2418 16.3052 0.0996 2.2150 122.5887 30.9044 21.9089 6185.1211 1061.0000 25.3191 29.0554 279.2054 16.6999 16.3922 52.7500 2.7718 2.6229 82,6829 104,6317 2.2294 2.3053 35,1235 121,5500 9572.0000 1.4519 1.5097 2.3149 438.4668 457.1536 154.8103 2.2472 23.1044 20.3082 0.0721 2.1991 28.2733 23.8269 6256.2881 1130.0000 25.6287 259.6840 17.2199 16.9122 2.3926 2.2807 72.1215 62.2323 2.1874 32.3575 119.7500 1121.0000 4,8307 107,4421 22.0096 -999.2500 2,1173 Tape File Start Depth = 7987,000000 Tape File End Depth = 9572.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 5 is type: LIS DEPTH ATCM ATDC BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 9572.0000 1.451 9 1.5097 2.3149 438.4668 457.1536 154.8103 2.2472 23.1044 20.3082 0,0721 2.1991 28.2733 23.8269 6256.2881 1130.0000 25.6287 259.6840 17.2199 16.9122 2.3926 2.2807 72.1215 62.2323 2.1874 32.3575 119.7500 9572.2500 1.4671 1.5241 2.3178 443.7819 448.7061 153.4428 2.2511 22.9359 20.1336 0.0633 2.2089 28.9621 23.4174 6271.2578 1129.0000 26.5065 264.8577 17.0316 16.7258 2.3615 2.2534 72.1215 68.8251 2.2286 33.0832 119.8062 9600.0000 1.2728 1.3342 2.2696 375.6620 440.9518 152.1994 2.2016 25.7568 23.0570 0.0682 2.1561 30.6808 22.3043 6259.9727 1127.0000 28.7569 277.5751 16.8603 16.5532 2.8172 2.6620 47.7171 49.2206 2.2678 34.8891 123.2375 1121.0000 4.8307 107.4421 22.0096 -999.2500 2.1173 1120.0000 4.7157 106.8712 22.8551 -999.2500 2.1569 1123.0000 4.0711 102.4035 25.0299 -999.2500 2.1939 9650.0000 1.1262 1.1875 2.4310 74.0000 325.7265 378.4955 141.6372 2.4069 3.5302 16.3140 13.2709 0.0175 2.3953 104.6544 26.3254 26.1076 6464.8057 80.0000 19.7087 23.2321 244.8977 15.4053 15.1028 55.28,33 3.2677 3.0701 74.1776 81.3802 2.5504 2.6420 30.2995 109.0625 9700.0000 1.0194 1.0811 2.4011 74.0000 291.0242 343.7578 135.3810 2.3720 3.5936 18.0617 15.0821 0.0296 2.3522 113.8208 25.8607 26.4127 6445.5684 81.0000 19.1805 22.6803 241.3488 14.5435 14.2441 54.7333 3.6779 3.4361 50.7225 47.8903 2.8041 2.9090 29.8072 112.0437 DEPTH CADE DPLM LPOM NPSM RACM RPDE ATCM CPDE DPSM NFBM NRCM RADE SPOM ATDC DCCM DRHM NNBM PDCM ROPA TCDM BDCM DLAM DSAM NPEM PDDC ROPS BDEM DPEM GRAM NPLM PDEM RPCM 9750.0000 310.5960 17.3095 23.7660 20.2930 3.4311 2.8560 1.0810 350.1421 14.3026 27.9759 225.3307 3.2196 27.5823 1,1416 136.5422 0.0134 6373.9395 14.7034 53.1186 114.8000 2.4140 2.4061 2.3972 73.0000 14.4050 52.7024 68.0000 3.5376 99.8664 16.9023 57.08,,33 2.7543 9800.0000 329.1253 14.8680 21.3680 17.7632 3.2338 2.5809 1.1360 387.4631 11.7723 30.6255 207.0915 3.0384 25.0229 1.1977 143.2121 0.0042 6412.8145 15.6222 94.5762 116.8250 2.4558 2.4547 2.4519 58.0000 15.3181 93.9002 53.0000 3.4964 95.7555 14.5000 38.8833 2.4920 9850.0000 355.7242 14.6579 23.1873 19.6714 2.9754 2.5948 1.2171 385.3877 11.5546 28.8O36 220,9130 2.8112 26.9658 1.2763 142.8281 0.0235 6429.5713 15.5693 61.1295 117.9500 2.4593 2.4358 2.4201 51.5714 15.2663 69.0964 50.2657 3.5106 112.4494 16.3114 42.88,33 2.5060 9900.0000 290.7242 12.5150 21.7722 18.1746 3.6784 3.0114 1.0192 332.0660 9.3337 30.7216 210.1511 3.4397 25.4552 1.0800 133.1746 0.0562 6527.9766 14.2395 106,0425 119.3225 2.4960 2,4398 2,4023 25,0000 13.9435 93.9002 21.5714 3.8012 135.5911 14.8898 16.2500 2.9027 9950.0000 503.8603 16.7137 25.4620 22.2132 2.0723 1.9674 1.6264 508.2809 13.6851 27.1988 238.3011 1.9847 29.3845 1.6829 162.7292 0,0245 6553.5889 18.3152 163.9622 120.8750 2.4242 2.3997 2.3~3 30.0000 18.0025 161.0657 28.0000 3.4990 104.0491 18.7339 23.2667 1.9081 DEPTH CADE DPLM LPOM NPSM RACM RPDE 10000.0000 323.1907 15.4755 24.8063 21.4579 3.2933 2.7362 10050.000O 317.9199 14.3020 22.8056 19.2541 3.3573 2.5973 10100.0000 343.7978 14.2406 21.6735 18.0736 3.0844 2.6676 10150.0000 236.9320 13.8323 21.5810 17.9792 4.5798 3.4311 10200.0000 400.6828 18.9784 24.9337 21.6034 2.6322 2.2280 ATCM CPDE DPSM NFBM NRCM RADE SPOM 1.1192 365.4663 12.4019 27.6878 233.2855 3.0941 28.6886 1.1013 385.0209 11.1857 29.7062 218.0042 3.1454 26.5589 1.1819 374.8682 11.1221 30.8172 2O9.4037 2.9087 25.3497 0.8435 291.4528 10.6990 30.8289 208.7028 4.2206 25.2508 1.3453 448.8384 16.0322 27.3269 234.2600 2.4957 28.8238 ATDC DCCM DRHM NNBM PDCM ROPA TCDM 1.1797 139.2505 -0.0037 6531.0000 15.0823 208.4001 122.0000 1.1637 142.7206 0.0022 6548.1006 15.5602 149.2162 123.5750 1.2413 140.9214 0.0154 6525.0166 15.3125 150.0693 124.4525 0.9368 125.2495 0.0124 6505.6455 13.1540 149.5091 124.5875 1.4051 153.4085 0.0369 6472.8115 17.0323 86.9627 124.3625 BDCM DLAM DSAM NPEM PDDC ROPS 2.4454 2.4477 2.4514 42.0000 14.7833 208.4638 2.4654 2.4632 2.4618 40.0000 15.2575 145.3975 2.4665 2.4510 2.4407 42.0000 15.0128 147.6618 2.4735 2.4465 2.4382 85.0000 12.8633 147.6818 2.3655 2.3482 2.3236 76.0000 16.7266 83.2298 BDEM DPEM GRAM NPLM PDEM RPCM 27.0000 3.6197 106.0878 18.0126 19.9500 2.6430 38.0000 3.8233 111.7675 15.9142 31.5333 2.5100 39.0000 3.7630 103.6765 14.7941 19.5&33 2.5777 79.0000 3.6885 114.4783 14.7047 67.1333 3.3033 73.0000 3.6046 109.0781 18.1514 50.7833 2.1580 DEPTH CADE DPLM II=OM NPSM RACM RPDE ATOM CPDE DPSM NFBM NRCM RADE SPOM ATDC DOOM DRHM NNBM PDCM ROPA TCDM BDCM DLAM DSAM NPEM PDDC ROPS BDEM DPEM GRAM NPLM PDEM RPCM 10250,0000 282.1024 13,7907 25.8975 22.7237 3.8O37 2.9859 0.9909 334.9075 10.6559 26.5130 241.6305 3.5448 29.8463 1.0530 133.6693 0.0497 6477.6074 14.3136 70,5732 124, 7000 2.4742 2.4124 2.3792 51.0000 14.0166 7O.4252 48.0000 3.5958 124.3,389 19.2221 38.3333 2.8802 10300,0000 319.1070 14.5009 23.6439 20.1589 3.3471 2.5086 1.1041 398,6332 11.3918 29,1044 224.3978 3.1337 27.4523 1,1673 145,0677 0,0354 6603,6016 15,8835 89.9111 124.7375 2.4620 2.4282 2.4046 52.0000 15.5806 86,4362 49.0000 3.6140 103.9189 16.7747 41.5000 2.4256 10350.0000 424.1274 15.1796 23.5472 20.0536 2.4865 1.9583 1.4084 510.6379 12,0953 29.0346 223.6599 2.3578 27,3494 1.4703 1 63.0920 0,0257 6565.9141 18.3651 120.1371 125.6000 2,4504 2,4217 2.4046 40.0000 18,0514 107.7091 37.0000 3.4794 109.2101 16.6745 28.4500 1,8993 10400.0000 201.6393 12.8969 23.7593 20.2857 5.4403 3.9222 0.7235 254,9573 9.7295 28.5357 225.2800 4.9544 27.5752 0.7877 117.6838 0,0049 6500.0234 12,1132 132.8891 126.9500 2,4895 2.4835 2,4803 99.0000 11,8276 150.3378 96,0000 3.7636 133,7615 16.8953 86.5167 3,7685 10450.0000 219,7055 14.0037 22.1809 18,5967 4.9725 3.5322 0,7843 263.1082 10.8766 30.9108 213.2520 4.5515 25.8920 0,8490 123,5556 0,0240 6665.1016 12.9208 103,4152 126,8656 2,4705 2.4511 2,4351 46.0000 12,6323 70.0062 43.0000 3.8006 117.2635 15.2902 33.2330 3,3997 DEPTH CADE DPLM LPOM NPSM RACM RPDE 10500.0000 212.6303 12.1936 18.6384 15.1338 5.1246 4.0891 10550.0000 200.6429 11.5074 19.6371 16.0666 5.4814 3.8401 10600.0000 559.3876 14.6525 28.5130 25.9324 1.8662 1.5621 10650.0000 569.0863 17.7886 28.5329 25.9577 1.8259 1.8939 10700.0000 108.7224 20.8600 22.7750 19.2215 11.1096 4.9322 AT. CM ..' CPDE DPSM NFBM NRCM RADE SPOM 0.7635 244.5515 9.0007 34.7150 186.6353 4.7030 22.0937 0.7186 260.4091 8,2895 33.7915 194.0742 4.9840 23.1674 1.7636 640.1624 11.5490 23.6747 261.4882 1.7877 32.6101 1.7934 527.9979 14.7991 24.2564 261.6376 1.7572 32.6310 0.3660 202.7473 17.9822 29.8396 217.7711 9.1977 26.5263 ATDC DCCM DRHM NNBM PDCM ROPA TCDM 0.8249 115.4312 0.0071 6551,1064 11.8038 112.3309 126.1625 0.7635 118.8341 0.0436 6630.9912 12.2713 115.2824 126.1625 1.8236 181.5875 0.0212 6259.5117 20.9065 I O5.7857 127.0250 1.8477 1 65.6765 0.0063 6416.9727 18.7205 93.3238 130.3625 0,4421 105.8303 0.0150 6570.4795 10.4867 56.1651 127.5125 BDCM DLAM DSAM NPEM PDDC ROPS 2.5015 2.4886 2.4838 52.0000 11.5193 106.0259 2.5132 2.4697 2.4406 40.0000 11.9867 95.0868 2.4594 2.4343 2.4202 233.0000 20.5870 104.6317 2.4058 2.4080 2.4037 81.0000 18.4089 114.4409 2.3533 2.3373 2,3273 107.0000 10.2125 49.9138 BDEM DPEM GRAM NPLM PDEM RPCM 48.0000 3.6330 122.2606 12.0160 39.5491 3.9261 36.0000 3.6170 148.5546 12.8957 28.3828 3.6917 228.0000 4.5208 153.8419 22.3019 212.6661 1.5191 72.00(X) 3.8733 174.9634 22.3263 46.8000 1.8381 98.0000 3.3288 163.9826 15.88.33 73.7000 4.7226 DEPTH CADE DPLM LPOM NPSM RACM RPDE ATCM CPDE DPSM NFBM NRCM RADE SPOM ATDC DCCM DRHM NNBM PDCM ROPA TCDM BDCM DLAM DSAM NPEM PDDC ROP$ BDEM DPEM GRAM NPLM PDEM RPCM 1 O75O.0000 36O.7285 15.7794 25.6510 22.5626 2.9268 2.7830 1.2340 359.3302 12.7168 26.5658 239.7461 2.7722 29.5850 1.2909 138.1431 0.0384 6439.8945 14.9298 61.4539 128.6375 2.4402 2.4292 2.4O36 104.0000 14.6319 45.2112 92.0000 3.5569 165.1758 19.0680 68.3667 2.6876 1O8OO.OOOO 539.O968 19.2337 29.478O 27.3636 1.9314 1.9344 1.7176 516.9452 16.2968 23.5658 268.7062 1.8550 33.6259 1.7729 164.0163 0.0023 64O2.6982 18.4922 73.6693 129.3125 2.3811 2.3739 · 2.3724 106.0000 18.1820 88.5971 97.0000 3.7919 183.2747 23.6822 73.18,33 1.877O 10650.0000 578.57O6 16.0377 27.1635 24.3976 1.7965 1.7816 1.8158 561.2955 12.9846 24.9125 251.2813 1.7284 31.1860 1,8710 170.5533 0.0110 6329.6680 19.3909 46.5095 1 29.7625 2.4358 2.4324 2.4251 118.0000 19.0782 48.1856 111.0000 4.2122 174.5668 20.8262 77.0000 1.7304 10900.0000 422.7212 17.9467 34.3035 34.0124 2.4862 2.2329 1.4085 447.8467 14.9630 20.3032 303.0964 2.3656 38.6736 1.4668 153.2919 -0.0124 6222.2637 17.0162 43.O422 130.7750 2.4031 2.3867 2.3991 104.0000 16.7105 26.6457 96.0000 4.6318 196.3163 3O. 1491 74.6333 2.1614 10950.0000 268.7632 14.8978 32.2739 31.1571 4.0041 3.0669 0.9482 326.0670 11.8032 21.36OO 289.O452 3.72O7 36.5570 1.0109 132.0376 O.O787 6242.6836 14.0888 42.8875 132.0125 2.4552 2.3832 2.3308 1170.0000 13.7945 38.5205 1163.0000 5.1694 263.3375 27.36O8 65.8667 2.9556 DEPTH ATCM ATDC BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 10955.0000 1.2578 1.3077 2.3753 1163.0000 366.3705 279.1323 122.8033 2.3013 4.9526 19.5744 16.6498 0.0546 2.2648 234.4088 32.9202 20.8606 6192.6416 1169.0000 28.2398 32.0591 293.5932 12.8173 12.5276 -999.2500 2.8595 2,7295 86.8172 63.1398 3.4438 3.5825 37.2320 132.0125 Tape File Start Depth = 9572.000000 Tape File End Depth = 10955.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units -- Feet Tape Subtile 6 is type: LIS DEPTH ATCM ATDC BDCM BDEM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM Il=OM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 10955.0000 1.2578 1.3077 2.3753 1163.0000 366.3705 279.1323 122.8033 2.3013 4.9526 19.5744 16.6498 0.0546 2.2648 234.4088 32.9202 20.8606 6192.6416 1169.0000 28.2398 32.0591 293.5932 12.8173 12.5276 -999.2500 2.8595 2. 7295 86.8172 63.1398 3.4438 3.5825 37.2320 132.0125 10955.2500 0.9469 1.0083 2.3643 11 63.0000 267.9351 309.9575 128.9443 2.2907 4.9818 20.21 40 17.3127 0.0685 2.2450 228.9735 33.2017 20.6776 6179.3125 1169.0000 28.6255 32.4543 295.5532 13.6628 13.3705 -999.2500 4.0103 3.7322 86.8172 78.9248 3.1069 3.2262 37.5257 132.0125 11000.0000 1.9144 1.9645 1.81 75 1213.0000 616.9802 486.7153 159.4708 1.8381 5.8280 52.1943 50.4559 -0.0176 1.8557 123.8814 43.8684 16.3723 5943.0977 1234.0000 43.7498 47.6922 359.0042 17.8668 17.5548 -999.2500 1.6756 1.6208 46.1487 46.0245 1.9903 2.0546 48.5220 132.63 13 11050.0000 1.1537 1.2162 2.4934 104.0000 335.2449 407.0878 146.5460 2.4675 5.0430 12.6652 9.4893 0.0145 2.4579 103.0429 23.7878 28.1860 6426.5635 114.0000 17.0748 20.4742 225.4975 16.0871 15.7844 42.7500 3.1754 2.9829 14.0881 13.0290 2.3747 2.4565 27.6055 130.2125 11100.0000 0.2439 0.3200 2.4747 44.0000 78.6539 152.8721 92.6819 2.4294 3.3892 13. 7575 10.6214 0.0475 2.3978 92.3957 14.6800 42.3206 6747.1172 51.0000 8.88,33 11.7983 157.6749 8.7376 8.4809 17.1667 16.5310 12.7139 35.9716 42.1891 6.2759 6.5414 17.8155 135.1625 DEPTH CADE DPLM LPOM NPSM RACM RPDE 11150.0000 -999.2500 4.4302 26.1736 23.2499 -999.2500 11.8324 11200.0000 -999.2500 9.4368 21.6885 18.2174 -999.2500 49.5673 11250.0000 -999.2500 14.7830 23.0414 19.6520 -999.2500 42.7063 11300.0000 -999.2500 9.3513 27.4461 24.8206 -999.2500 18.8209 11350.0000 -999.2500 -8.9541 29.5377 27.5278 -999.2500 22.9540 ,_,.,.,~,'rnM - ~. ATDC CPDE DCCM DPSM DRHM NFBM NNBM NRCM PDCM RADE ROPA SPOM TCDM -999.2500 84.5140 0.9549 26.4987 243.7391 -999.2500 30.1388 -999.2500 20.1746 6.1436 31.5449 209.5173 -999.2500 25.3658 -999.2500 23.4158 11.6842 29.8780 219.8007 -999.2500 26.8103 -999.2500 53.1323 6.0550 26.0730 253.4276 -999.2500 31.4846 -999.2500 43.56,53 -12.9160 23.8353 269.1505 -999.2500 33.6887 -999.2500 70.8557 -0.0142 6530.6143 5.8278 50.9126 135.8375 -999.2500 38.3865 -0.0133 6682.7197 1.9246 46.8075 135.5000 -999.2500 40.7873 -0.0358 6640.2539 2.1787 49.9935 135.6125 -999.2500 57.7239 -0.0307 6681.1143 4.1545 62.5860 136.1750 -999.2500 52.9625 0.1829 6486.6338 3.5728 57.0373 137.3750 BDCM DLAM DSAM NPEM PDDC ROPS 2.6342 2.6707 2.6849 46.0000 5.6080 51.3606 2.5486 2.5712 2.5844 39.0000 1.8013 46.3558 2.4572 2.4793 2.5151 51.0000 2.0461 49.9138 2.5501 2.5829 2.6136 47.00(X) 3.9663 72.3242 2.8631 2.6802 2.5582 46.0000 3.3988 38.9438 BDEM DPEM GRAM NPLM PDEM RPCM 41.0000 8.5991 75.6267 19.7257 23.0O00 11.2705 32.0000 6.3919 46.1731 14.9304 13.1000 46.4787 43.0000 5.0500 38.7~ 16.2925 13.3167 40.1026 40.0000 6.5897 62.1496 21.2325 16.1833 17.8270 40.0000 11.4134 64.4694 23.8408 15.1833 21.6962 DEPTH ATCM ATDC BDCM BDEM CADE CPDE DCCM DL.AM DPEM DPLM DPSM DRHM DSAM GRAM LPOM NFBM NNBM NPEM NPLM NPSM NRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE SPOM TCDM 11400.0000 0.2174 0.2908 2.5088 51.0000 71.6535 130.3824 86.1771 2.5061 6.3368 11.7634 8.5548 -0.0097 2.5158 66.5766 25.4899 27.1621 6550.6104 70.0000 18.9426 22.4316 238.5145 7.8597 7.6124 19.18,.33 17.5306 13.9560 40.8691 38.0629 7.3445 7.6697 29.4141 137.1875 11450.0000 0.4928 0.5596 2.5778 42.0000 138.8.961 193.9923 103.4412 2.4610 4.0873 7.7293 4.3740 O. 1203 2.3807 63.4620 15.1713 41.5750 6777.5840 50.0000 9.2607 12.2013 161.2273 10.2014 9.9299 18.5833 8.2148 7.1996 45.7507 46.9501 4.9565 5.1548 18.3485 139.3250 11500.0000 0.8351 0.8978 -999.2500 234.1276 284.2719 123.5511 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12.9590 12.6712 4.5539 4.2712 52.6668 48.8281 3.5178 -999.2500 1 40.8437 -999.25OO -999.2500 49.O833 -999.2500 17.7667 3.3999 11525.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 39.3775 39.3775 -999.2500 -999.2500 -999.2500 141.2375 Tape File Start Depth = 10955.000000 Tape File End Depth = 11525.000000 Tape File Leve~ Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 7 is type: US
