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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-06A PRUDHOE BAY UNIT 13-06A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2025 13-06A 50-029-20642-01-00 197-218-0 N SPT 8614 1972180 1800 49 2524 2480 2460 0 0 0 0 REQVAR P Kam StJohn 6/7/2025 MIT-T per AA AIO 4F.004 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 UNIT 13-06A Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250607185902 BBL Pumped:2.1 BBL Returned:2.2 Friday, July 25, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-06A PRUDHOE BAY UNIT 13-06A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 13-06A 50-029-20642-01-00 197-218-0 W SPT 8614 1972180 1800 1002 1002 1000 1000 5 4 4 5 REQVAR P Bob Noble 6/5/2025 2 year MIT-IA to max injection psi per AA AIO 4F.004 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 UNIT 13-06A Inspection Date: Tubing OA Packer Depth 1 2408 2279 2237IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250616212608 BBL Pumped:1.9 BBL Returned:1.1 Thursday, July 24, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-06A PRUDHOE BAY UNIT 13-06A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 13-06A 50-029-20642-01-00 197-218-0 N SPT 8614 1972180 1950 34 2504 2423 2385 0 0 0 0 REQVAR P Guy Cook 6/9/2023 2 year MIT-T per AA AIO 4F.004 to max anticipated injection pressure. The header pressure is 1950 psi. Testing was completed with a Little Red Services pump truck and calilbrated 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 UNIT 13-06A Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230608184108 BBL Pumped:2.4 BBL Returned:2.3 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 9 2 year MIT-T per AA AIO 4F.004 James B. Regg Digitally signed by James B. Regg Date: 2023.07.27 10:53:13 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-06A PRUDHOE BAY UNIT 13-06A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 13-06A 50-029-20642-01-00 197-218-0 W SPT 8614 1972180 2154 1575 1580 1607 1632 3 4 3 3 REQVAR P Kam StJohn 6/3/2023 2 Year MIT-IA Per AA AIO 4F.004 to max anticipated injection pressure (Header pressure = 1950 psi) 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 UNIT 13-06A Inspection Date: Tubing OA Packer Depth 9 2419 2274 2242IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230603103342 BBL Pumped:1.1 BBL Returned:1 Tuesday, July 25, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 2 Year MIT-IA AIO 4F.004 James B. Regg Digitally signed by James B. Regg Date: 2023.07.26 11:38:18 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor � I //G"f 7z7C'z_{ FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 9, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-06A PRUDHOE BAY UNIT 13-06A Src: Inspector Reviewed By: n P.I. Supry J�1` Comm Well Name PRUDHOE BAY UNIT 13-06A API Well Number 50-029-20642-01-00 Inspector Name: Jeff Jones Permit Number: 197-218-0 Inspection Date: 6/8/2021 - Insp Num: mitJJ210628152949 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-06A Type jnj N j�7j) 8614 I Tubing 646-- 2249 2162 - 2129 . PTD 1972180 Type Test SPT (Test psi 2050 IA o 0 0 0 BBL Pumped: z.3 ` BBL Returned: 2.l OA o 0 0 0 -- Interval REQvAR P/F P �_ - -- Notes: MIT -T, IA and OA cemented.TTP set @ 10,377' MD. 1 well inspected, no exceptions noted. AIO 4F.004 to MASP of 2050. Friday, July 9, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �,� 7I 141 4,011 DATE: Wednesday, July 7, 2021 P.I. Supervisor l SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-06A FROM: Adam Earl PRUDHOE BAY UNIT 13-06A Petroleum Inspector Sre: Inspector Reviewed By: P.I. Suprv. X11 -� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-06A API Well Number 50-029-20642-01-00 Inspector Name: Adam Earl Permit Number: 197-218-0 Inspection Date: 6/4/2021 Insp Num: mitAGE210607111647 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-06A ;Type jpi W -V D 8614 Tubing 656 656 - --------___ 656 " 657 �. _ _ PTD - -- 1972180 'Type Test — sPT" ---- Test psi! = -- IA 537 2312 - 2196 2168 1 — BBL Pumped: 0.7 ' !BBL Returned: 0.6 OA 0 0 ! 0 0 Interval REQvARP/F P - --- Notes: MIT IA tested as per AIO 4F.004 to max Ant. Inj. Psi of 2050. Wednesday, July 7, 2021 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, June 8, 2021 P.I. Supervisor �? ��tljZOl/ SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-06A FROM: Adam Earl PRUDHOE BAY UNIT 13-06A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry UC�--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-06A API Well Number 50-029-20642-01-00 Inspector Name: Adam Earl Permit Number: 197-218-0 Inspection Date: 6/42021 IBsp Num: mitAGE210607111647 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-06A .Type Inj W .TVD$614 - Tubing 656 656 ' 656 - 657 - PTD 1972180 - Type Test SPTTest psi 2154 IA 537 2312 - 2196 - 2168 ' BBL Pumped: 0.7 'BBL Returned: 0.6 OA o a 6 0 Interval REQVAR - WIT P Notes: MIT IA tested as per AIO 4F.004 to max Ant. Inj. Psi " r� Tuesday, June 8, 2021 Page I of 1 Wallace, Chris D (CED) From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, February 24, 2021 11:16 AM To: Wallace, Chris D (CED) Cc: Alaska NS - PB - Field Well Integrity _ C� Subject: RE: [EXTERNAL] FW: PBU 13-06A P / f —7 z (D Chris, The two test events on 13-06A would need to happen on different days due to the MIT -IA being an online test and the MIT -T happening with the well SI and a plug set. We have internally discussed aligning the two tests and have no problem with that request. Per AIO 4F.004 condition 8, the anniversary date is based off the date of the first passing MIT -IA which was 6/19/2017, therefor I will align the MIT -T and MIT -IA for June 2021. Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki(@hilcorD.com From: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Sent: Tuesday, February 23, 20211:30 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] FW: PBU 13-06A Oliver, Please review and get back with me on this. PBU 13-06A is an injector with Admin Approval (AIO 4F.004; 7/9/2015). Rule 3 requires a MITIA every 2 years; Rule 4 requires a MITT every 2 years; anniversary date is July 2015. Most recent tests for PBU 13-06A are: - MITIA on 6/19/2017 - MITT on 11/3/2018 - MITIA on 6/6/2019 - MITT on 11/24/2020 The well has been on continuous water injection since June 2017 and I don't see any reason why the MITT had to be delayed. Of course the well has to be SI to do the MITT but there does not appear to be any reason for the tests to be separated by 6 months — I don't think the Admin Approval provides for that. To be consistent with the Admin Approval, I think Hilcorp should perform both MITT and MITIA in July 2021, then every 2 years thereafter— in July. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7`h Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, December 8, 2020 To: Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-06A FROM: Brian Bixby PRUDHOE BAY UNIT 13-06A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-06A API Well Number 50-029-20642-01-00 Inspector Name: Brian Bixby Permit Number: 197-218-0 Inspection Date: 11/24/2020 IDsp Num: mitBDB201124154506 Rel Insp Num: Packer Depth Well 13-06A Type Inj I NN ' V T 8614 Tubing PTD 1972180 "Type Testi SPT (Test psi 2154 IA BBL Pumped:tL 16 IBBL Returned: 1.6 OA -- Interval REQvAR P/F P Notes: MIT -T As per AIO 4F.004, MIT -IA was completed 6/6/19 Pretest Initial 15 Min 30 Min 45 Min 60 Min 737 20992046 2023- 12 13 - 12 12 0 o I o o -- Tuesday, December 8, 2020 Page 1 of 1 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg '( DATE: Wednesday, June 12, 2019 P.I. Supervisor i 1 SUBJECT: Mechanical Integrity Tests 778 n8_ 1 778 BP EXPLORATION (ALASKA) INC. YP a Test SPT Test psi 13-06A FROM: Matt Herrera PRUDHOE BAY UNIT 13-06A Petroleum Inspector -'T 09 BBL Returned: 0.8 OA Sre: Inspector 0 I--] o Reviewed By: R n _ P.I. Supry V NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-06A API Well Number 50-029-20642-01-00 Inspector Name: Matt Herrera Insp Num: mi[MFH]90606123951 Permit Number: 197.216-0 Inspection Date: 6/62019 - Rel Insp Num: Wednesday, June 12, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I306A Type lnj i w";TVD 8614 Tubing 778 778 n8_ 1 778 PTD 1972180r YP a Test SPT Test psi 2200 IA —1 120 2200 ' --- 2067 -, 2052 '. -�-- -'T 09 BBL Returned: 0.8 OA o 0 I--] o -BBL-Pumped: In[erVel-. _ - R - -_ - - - - - -P-_— Notes: AIO NO. 4F.004 Variance IA pressure tested to maximum A1P ✓ aAAjp. Ak4 iAAec%' r Presses e Wednesday, June 12, 2019 Page I of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:OA Squeeze IJ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 197-218 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service H 6. API Number: 50-029-20642-01-00 7. Property Designation(Lease Number): ADL 0028315 8. Well Name and Number PBU 13-06A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RFCEIVED 11.Present Well Condition Summary: 9 6 Total Depth: measured 11094 feet Plugs measured 10377 feet JUL. 2 f 017 true vertical 9356 feet Junk measured 10966 feet Effective Depth: measured 10377 feet Packer measured 10347 feet AOGCC true vertical 8648 feet Packer true vertical 8617.68 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 81 20"91.5#H-40 31-111 31-111 1490 470 Surface 2627 13-3/8"72#L-80 30-2658 30-2658 4930 2670 Intermediate 6933 9-5/8"47#L-80 28-6961 28-5926 6870 4760 Production Liner 4297 7"26#L-80 6775-11072 5792-9334 7240 5410 Perforation Depth: Measured depth: 10612-10668 feet 10682-10707 feet 10727-10741 feet 10756-10802 feet True vertical depth: 8880-8935 feet feet 8949-8973 feet 8993-9007 feet 9022-9067 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED Treatment descriptions including volumes used and final pressure: JAN 2 3 ZU!8 5/28/16:7 Gallons SqueezeCrete Cement,1500 psi. 8/6/16:1.5 Gallons SqueezeCrete Cement,3000 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -9290 1090 740 Subsequent to operation: -7536 290 600 14.Attachments:(required per 20AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ H 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: 316-202 Authorized Name: Kristin Odom Contact Name: Kristine Odom Authorized Title: DS 06&13 PE Contact Email: Kristine.Odom@BP.com ileAuthorized Signature: 6_______ Date: 7/2.1//0017 Contact Phone: 564-5365 Farm 10-404 Revised 04/2017 f/rL I/'Z/`S .4e/" RBDMS V- J U L 2 7 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED JUL 26 2017 RE: BP Exploration (Alaska), Inc. AOGCC Report of Sundry Well Operations Summary July 24, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for OA Squeeze Sundry # 316-202 for Well 13-06A, PTD # 197-218. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. 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WaDv) °1' O ~ O o < m 0 °,2. < c0J0ZD - � 0 — O ,- N lzN- p0 - F- > Q o A (X a- �n IQ. - Qwzw (1°° I` I. 01.0Nr a) - OUad � II m n cnii E0 11mw v * E0 - > - zr-- Nwo coN o -° gmD1 Q � > II > a) Q- aoi 1 co ° ma a * a) � aw' 0 (7pN § W - ~ o cn 00O � Nn O QU EU) 1 D0) 0 Ij ,r) c NQF- JWJ = � E (O ° DWJpW °45a ZO EU2° o * Z N O J N p 7 Z Z a Ct _2 O m o p w 2 ° Z650. 0- 11 O N 1 ZWW > 2 > Z 'c - UXp °6 -10_ - - �� 3WaO00o > 0 > 0 ° Q a - p 13 CO00) - - wWl- a) N co oZ_ - � � (nQ (W � W > c0 E O N CO O V O c a) ` a° g 0 O O Ups a° � U > "aU J 'nr` WJWZ '+, L a) o oF- - _i Cn m M in CV 2 m II * * W 4 N M Q I m e Z N W J �� 0 > (Ii R U O J O o O o u' U) cnc 0 N d J W O II II O Q -JU) F- QO -3ON CD -, m a 0_ 0 (.11- 0) _J O , O O �-3 * W OO * = * Q W EtOD * * LCp * WD * 7 > � > cJ * JF._ t F- O Q« Et U) JW 0 : O - .E : U) J W : F- u) cAF- (1) F- LL : CO CO O CO O N- O O O O O O O N r- co co co N 0 N- •- N- N- • • a) o a) 0 U O C a C as , yo CL N 6 o_ Nn Q -o -, a C E O O o . -O MOa) a ' U COC6 C) Q QCn rE .0 — — a) C -0 C r - CO m O O C N `o o CS Ca II - II a) C6 .- (7) C O O ") O E O E a a) U E) o_.- -0 Cn a) o co (n oti u Y -o L `- a) .= a) -6 a) ) ,- a) o U' 0 N c Q U co a) a) co CO O c a II fl- co O �1 a a) N 00) C6 O co Et- J o 0 CO C V a U - N r 0 CZ J • �V) O C6 •C D M sZ C LL .c C2 (n 0 co co O a Q .Q- O O a) O> 00 O O II H CO 0:) E C 'o +. N -- M r co O Z > O p -0_ C 2 5 N a .�...° > O N O"- O > U) CD O 7 N Q a U) CZ a) > a a C F 0 0 ,_ C o c < CD a) Q a) O - 0 0 m > U) C6 O cn o r m _ cu O cYii ---: 02o o u) ' .E 'o > a &) E �+ II (� U O > CO L C6 CCI �—, U) ca J L > C ep a) < o to H II IL 0U a) C Q E a) I.= LL = �6o a) •- o m . CDa 0r O - O O � a D Q szcn Q Q Q ao � � � EUS c N Q m � Sao 0 C a) c cin ~ 0 C r C $ O r a) N O = o r Q L •E d— p d Ci•E � �L , 0 � 8 . o 0 .() 0 7 6 0 cn 0 0— a o = L1 � � -o v p => 0_¢ >= coOU uoitoi°i.i0 = O - -o 1.1 II > 0 > M II 0 — N . 11 > II 0 ~ O O = a Q C O Q C O U L. m O 0000 • , - CDO0 = C E o O • o n U -C vo) in o o a) v C� () o CT) C 11 O Qv � 0r `n Cf) Q 7, c OQ 'n Q * C m Q U) Cn 0 r C6 I I ii V 11 v.V' 0 'E C o_ r c O 0 .(o C CD Q Q N O II II r C2 E a_ ° > nCLtiO � � Q0O sz� O II U) 0_o E C E II a) — L CO II •- 2 II O - �+ U) o M a) O > sz ai +. O U II 'C II a J E w U 1 U Cn II N > > O > > E r r O > a) > _ — N ctS Q N — a) > a E . OU) o c6 > o t c oM > = w - c m E• •C j o r ° j ~ �` (� a) > o O > ~ m a) E 0 r O (o V s2. U) r Cn U) C) J a) ~ O U) �� p a w U) r0 r CI g-- u) 6 0-c0 CD 0 Cho r N N CI r O O J CO M lvJ j N O > LCA Z O •C a) o ii OamUO map E c� 11 w n co o0U II mU II 00 0)� o oY � 11 0 a) L - 11 0 a) 11 O a C _ � 0 ,; > � U > - F- ' > - o Na a) > - 0 > - a2 o ( a) -,-,i) o a) a C2 U) 1= •c U m '6 U) 1= M -0 Q .-. U) 1= .E U) F- a U J CD Z .- l'-- r N- r` ti r r r rr O CD CD O CD CD cn M CO N N N N N N _ o V N O to co v' co 6) CD r CO N V' r r _r r N N CB (0 (0 O CO (0 .TREE= " 6 X 7 CNV FLS • I WELLHEAD= GRAY GEN 4 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= CAMERON 13-06A WHEN ON ML WELL REQUIRES A SSSV WHEN ON OKB ELEV= 78' MI. BF ELEV= 7 C;:' , . KOP= 3096' —1600 j--jTOP OF IA CMT(09/27/15) 1 Max Angle= 51°@ 5196' ' Datum MD= 10606' � 1784 112 BKR CMT RETAINER(10/15/15) � ill �5 _- -- -. Datum TVD= 8800'SS 1788' 5-1/2 VVFD 1 TRP PATCH ID=2 965"(10/23/16) i E',41 =, 1800'-1806' —{TBG/CSG PUNCH(10/03/15) Ar 11 2191' i--Li 5-1/2"CAMCO HAI-O NIP,D=4 562" J 13-3/8"CSG,72#,L-80,ID=12.347" H 2660' 1 5-1/2"TBG, 17#,L-80,0.0232 bpf,ID=4.892" — 6684' ! l__ 6684' j--15-1/2 X 4-1/2"XO J [TOP OF 4-1/2"TBG 1--f 6684' L TOP OF 7"LNR H 6772' h Minimum ID = 2.313" @ 10377' 09-5/8"WINDOW 6958'-6998' 4-1/2" X 2-7/8" NIPPLE REDUCER 10272' H4-112 CMT RETAINER W/SLDNG SLV(09/15115) I •• ( 10290' 10295'. TBG PUNCH(09/15/15), ITOP OF WHFSTOCK 1—I 6988' 1 ,.. ._ ___ ____-- ___ _____—_ * 10343' 7"X 4-112"BAKERS 3 PKR D=3.88" ,� 10377" j-14-1/2"HES X NP,ID=3.81" , `y 10377' -14-1/2"X 2-7/8"NP REDUCER, D=2.313 (09/29/16) 039 1 19' 1—�4-1/2"TUBING TAL WLEG j TOP aF CEMENT �— 10360' WIR __--___ -_ _ -____... _.__ '.'./SVASS'1 [ 10400' --j ELMD TT LOGGED 02/11/98 1 9-5/8"CSG,47#,L-80,D=8.681" H 10752' 44••••••• 1 D 4-1/2"TBG,12.6#,L-80,0.0152 bpf, =3.958" )—{ 10399' 10966•CTM —FISH 2 CBPS MILLED DH (11/13/15) ,,PEFFORATION SUMMARY REF LOG-BHCS ON 01/11/98 • 4e ANGLE AT TOP FERE 10°@ 10612' t`Ei;\1/. Note.Refer to Roduction DB for historical pert data 7'LNR,26#,L-80,0.0383 bpf, 11069' \��\.,1\��\ SIZE SPF INTERVAL Opn/Sqz SHOT SQZ ID=6.276" `i`,;\' 3-3/8" 6 10612- 10668 0 02/04/00 3-3/8" 6 10682- 10707 0 02/04/00 3-3/8" 4 10745-10759 0 02/11/98 TD — 11094' 3-3/8" 4 10774- 10820 0 02/11/98 DATE I REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 09/10/81 ORIGINAL COMPLETION 03/02/16 MGS/JMD SET 4-1/2"PX PLUG(02/29/16) WELL. 13-06A 02/11/98 WORKOVER 03/16/16 RB/JMD TREE 00(03/13/16) PERMIT No- 197-2180 03/05/01 SIS-MD FINAL 10/03/16 JTG/JMD FULLED PLUG/SET NP RED(09/29/16) All No 50-029-20642-01 03/11/02 RN/TP CORRECTIONS 10/24/16 BTN/JMD SET PATCH(10/23/16) SEC 13,T1 ON,R14E, 1643'FEL 8 80'FWL 10/28/15 NXWTTLH BKR CMT RTNR TAG(10/15/15) I BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday,June 23, 2017 5:24 AM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;Sternicki, Oliver R;Worthington,Aras J;AKIMS App User Subject: OPERABLE: Injector 13-06A(PTD#1972180) Passed AOGCC MIT-IA All, Injector 13-06 (PTD#1972180) passed an AOGCC witness MIT-IA 2,231psi on 06/19/17 demonstrating two competent well barriers. The well is now classified as Operable. Please reply if in conflict, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 SCANNED ,JUL 1 4 2017 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 22,2017 TO: Jim Regg SUBJECT: Mechanical Integrity Tests P.I.Supervisor (�/�2 7/J' BP EXPLORATION(ALASKA)INC. l 13-06A FROM: Jeff Jones PRUDHOE BAY UNIT 13-06A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-06A API Well Number 50-029-20642-01-00 Inspector Name: Jeff Jones Permit Number: 197-218-0 Inspection Date: 6/19/2017 ✓ Insp Num: mitJJ170620190440 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-06A Type Inj W .TVD 8614 " Tubing 552 552 552 552 - PTD 1972180 Type Test Test psi 2154 IA 0 2387 " 2256 2231 BBL Pumped: I ✓ BBL Returned: 0.8 ✓ OA 9 8 _ 8 L 8 - Interval REQVAR P/F P Notes: 2 year MIT,inner annulus cemented to+/-1600'MD.Sundry#315-264. 1 well inspected,no exceptions noted.MO 2F.004 Miert s,� zf zot 4 eLcccp dals o sb S" -ie-341 IA 11 f(o SCANNED AUG 2 2 2017 Thursday,June 22,2017 Page 1 of 1 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday,June 16, 2017 9:02 AM To: AK, GWO Well Integrity Engineer Subject: RE:Questions about AIO 4F.004 for PWI injector 13-06A (PTD# 1972180) Matt,Joshua, Thanks for the call and follow up on this. As discussed, with the accompanying MITT from 11/08/2016 that would push the next required MITT to 11/08/2018. There is no need to repeat now unless you wish to try to get the MITT on the same schedule as the MITIA. Regards, Chris From:AK, GWO Well Integrity Engineer [mailto:AKGWOWellSiteEnginee@bp.com] Sent: Friday,June 16, 2017 8:35 AM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Subject: FW:Questions about AIO 4F.004 for PWI injector 13-06A(PTD#1972180) From: AK, GWO Well Integrity Engineer Sent: Monday, June 12, 2017 2:12 PM To: 'chris.wallace@alaska.gov' Cc: Hibbert, Michael; AK, GWO Well Integrity Well Information; AK, GWO SUPT Well Integrity; AK, GWO Projects Well Integrity Subject: Questions about AIO 4F.004 for PWI injector 13-06A(PTD# 1972180) Hi Chris, I was looking over the AA for 13-06A(PTD# 1972180)and had a questions about the requirement for the MIT-T. The AA specifies that the MIT-T shall be performed every 2 years and that the AA anniversary date will be set by the initial MIT- IA date, but it doesn't state if an initial witnessed MIT-T needs to be completed. I know in the past we have used non witnessed test for the initial MIT-Ts for AA injectors but wanted to clarify with you before I made that assumption. BP did perform a passing MIT-T on 11/18/16 but as to my knowledge it was not witnessed nor was the state notified for witness. I have attached the 10-426 with the MIT results for the non-witness test done on 11/18/16. Please advise if an additional MIT-T needs to be completed. Thanks, Joshua Stephens SCANNED JUN 2 3 201 Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO 1 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,June 13, 2017 2:55 PM To: AK, GWO SUPT Well Integrity;AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead;G GPB FS3 Drillsites; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK,RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AKIMS App User Subject: UNDER EVALUATION: Injector 13-06A(PTD#1972180) Place on Injection for Warm Up Prior to MIT-IA- Extend Evaluation for Additional 28 Days All, Injector 13-06A(PTD#1972180)was made under evaluation on 5/18/17 to asses a remedial IA and OA cement squeeze. Due to operational constraints the well has not been put online and is approaching the end of the 28 day evaluation period. At the time the Under Evaluation clock will be rolled to allow an additional 28 days for diagnostics and AOGCC testing. Please reply if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 SCANNED ,1!.)jet ?I)1 Cell: 907-341-9068 WO .r......+.«w.x., F , .•• GWO Well Integrity Engineer Sent: Thursday, v 017 7:46 AM To: AK, GWO Well Integrity Eng - • AK, GWO SUPT Well Integrity; AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Leas, - PB FS3 Drillsites; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; '• EOC Specialists; AK, OPS Prod Controllers; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; A t-,, • Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgome avis 3; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Worthington, Aras 3; AKIMS App User Subject: UNDER EVALUATION: Injector 13-06A(PTD #1972180) Place on Injection for Warm • • . for to MIT-IA 1 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 18, 2017 7:46 AM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers;Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Worthington,Aras J;AKIMS App User Subject: UNDER EVALUATION: Injector 13-06A(PTD#1972180) Place on Injection for Warm Up Prior to MIT-IA All, Injector 13-06A(PTD#1972180) is a PWI injector with a known production casing leak and known inner by outer annulus communication (IAxOA comm)that was mitigated by an IA and OA cement squeeze. A subsequent passing MIT- IA to 2500 psi was performed post squeeze on November 05, 2015 demonstrating two competent barriers to formation. The cement bond log run on October 02, 2015 following the IA squeeze confirmed top of cement as stipulated in sundry 315-264. A water flow log run on 1/29/16 confirmed that there is no significant flow behind pipe. The well has been reclassified as Operable and now operates under Administrative Approval AIO 4F.004. The AOGCC have granted permission to place the well back on water only injection. Once the injection rate is stable,a witnessed MIT-IA will be scheduled. The well has been reclassified as Under Evaluation. Be mindful of low volume,fluid packed annuli, specifically the inner annulus which has been cemented to 1600ft. Plan Forward: 1. Ops: Place well on injection, DHD to assist/bleed pressures 2. DHD: Perform state witnessed MIT-IA Please respond if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) SCANNED t"A`: 3 Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 • • L OF T$ • 44, I// 7 sv THE STATE Alaska Oil and Gas ti ` ia Of/� T /� 1Cr�T //y� Conservation Commission - S JC`�l 1 ''INN t .1 333 West Seventh Avenue " `- ' Vil"*� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 FALAA‘ Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 � � � t Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-06A Permit to Drill Number: 197-218 Sundry Number: 316-202 Dear Mr. Worthington: 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, //' -eic& Cathy P. oerster , � Chair DATED this /5'day of April, 2016. RBDMS LI- MM 1 8 2016 K L lii U STATE OF ALASKA MAR 2 9 2016 •ALASKA OIL AND GAS CONSERVATION COMM N / APPLICATION FOR SUNDRY APPROVALS 'QTS T ii slits . 20 AAC 25.280 nOGCC 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well El• Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA Squeeze Ef' tmeeraav rwl/5 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 197-218• Exploratory 0 Development 0 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20642-01-00 ' 99519-6612 Stratigraphic 0 Service El. 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 ll PBU 13-06A • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028315 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi):_ Plugs(MD): Junk(MD): 11094• 9356 . 10377 8648 10377 10966 Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20"91.5#H-40 31 -111 31 -111 1490 470 Surface 2627 13-3/8"72#L-80 30-2658 30-2658 4930 2670 Intermediate 6933 9-5/8"47#L-80 28-6961 28-5926 6870 4760 Production Liner 4297 7"26#L-80 6775-11072 5792-9334 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary Ef Wellbore Schematic f 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service E• 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ El WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG II . GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer Signature / ANIV Phone +1 907 564 4102 Date 3 /�?//4if, )C. COMMISSION USE ONLY f �// Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 \CR - Z-0 2 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test�^ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes No ❑/ Spacing Exception Required? Yes El No Lf Subsequent Form Required: /0—404. .)v-4-11.--- APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: q_:-/ -4, V L 4/14-/L- O RI G I N A L RBDMS PR 1 8 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. y Attachments in Duplicate At//Ir% . ‹L 3,- ,/4 • • a) N m• I— M V r O CO C7 d) r QV V' co 0 N- p co O) d) O O p r 00 00 d7 O) > I- a O I- V' Ln 00 ‘,- .c .c 6) IC) O O O O) 00 C7 a 6) I- O) N W 0 CO O) O) O > p rco00coa) 0 Lu ❑ W ❑ ❑ Z W w 0w 0 a_ g g Y U 0 0 m O O W Y Y CO I"- r N U (n J U U w w C t (O O V O J J J Q Q fn w tY OD 0 0 0 0 U_ U_ _U -J W Z r r r r Z Z Z J J N m ❑ ❑ a W a U 0 0 W ❑ ❑ ❑ o ❑ z 0 < 2 2 2 CL 0 Q) � � � � CO CO QI a M F _ c N N I— • r 00 N LC) mp O O O O N r r r � ns O a u) = 0 0 (/) 2 2 0 cn cn cn cn cn w CL 0 U .°• N U) (!) U) U) 0a a d d a 0 a) a) a I- oco (OcocO ❑ 0 0 • N 0 0 0 0 W J J Z N N N N Z 1 1 Q w 1-4 00 03 0) CD CD a w .LJ ❑ _ ❑ W o N N N N Z a W W LL W Cir N N Q ❑ J J J J -10r:[ IL 0 ¢ < O U)) IL LL u_ cn a x E Q Q Q Q Q Z m CO CO CO CO 0 0 0 0 0 N t� C00-N 0- a a OUJW CC O O w a _ r r r r Q Q m m LL LL CO (n O • • • a) Q O 0 0 0 0 0 N- CO '- 00 0 - V V N b0 0 N •c In CO N- U 1 0 0 0 0 0 0 i 0) M I� V M V 0) CO N N - m V" CO (` CO CO CO CO N M N I� CO O co I� CO N lf) CA U) CO I- N CO c- O CO 6) U) N M M N N- N U) LC) E CO ELc) CO c E N CO O) O p c 4-0 "111„,. 2 Q OLO CO N- O 00 N- CC) CO M M N N O _Cr) CO CO _ r � W aO O MO O 00 ▪ J O,o MO co, J w % -J •y • CO-f U -• E N N O 0) L t 4- N. CO I"- N U) = 00 CO 0) N CO I- a N M 'I' CO M W 0)O - _ H W 0 .(7) U W U o � a D Z z Z W w m m O DI— Z D D U O) Z J F • • a) U 0_ O ^L 0 C ^O 2 i.(. . 2 0. `M a) ;•,7, vJ o (7 U � O 0 d = N m 1:1) Y 4 N ct S m X V ti 40 itt N co oco " m ' 00 1 C cv N L CD a) a) CO 0 M EL 2 c O ctW U E < < co CD CD Z o 0 • i • 0,7 13-06 OA Cement Squeeze Interventions Engineer: Aras Worthington (907) 564-4102 Pad Engineer: Irwin Chou (907) 564-5538 History 13-06A was drilled as part of the Pattern Reconfiguration Project targeting watered out 9-spot patterns and turning them into 5-spot WAG patterns in early 1998. The OA shoe was cemented and arctic packed by the rig via OA downsqueeze. The well was SI in Feb. 2014 due to the well developing an OA leak, where the pressure build up rate was not manageable by bleeds. It is also not eligible for an AA. The well has passed an MIT-T and MIT-OA, but failed an MITIA. A PPPOT-IC failed where it was determined that the secondary seals are bad, but the primary seals were holding. Since the IC was ruled out as a leak path, a LDL found a PC leak @ 238' ELMD. An OA cement squeeze was pursued to mitigate the PC leak. The IA was first cemented up to -1600' MD. Perforations were shot through the tubing and PC @ -1800' MD. Arctic pack was circulated out of the OA and replaced with cement to surface. After the cement job the MITIA to 2500 psi passed on 11/5/2015. A Water Flow Log performed for the AA showed no flow behind pipe. However, a subsequent MITT to 2500 psi on 3/16/2016 failed and indicated communication to the OA. Current Status The well remains "Non Operable" due to TxOA communication during the MITTs. The well is - therefore shut-in until the TxOA communication is remedied. Objective The objective of this job is to squeeze cement into the OA, fill the cement micro-annulus in the OA. • • • Procedural steps Special Projects 1. Pump sealant into the OA via the casing valve and squeeze to 2000 psi. Fullbore 2. MITT to 2500 psi. Slickline (contingent- if MITT unsuccessful) 3. Pull TTP. 4. Set nipple reducer & plug in tubing tail. EL (contingent- if MITT unsuccessful ) 5. Set tubing patch across perforations @ -1800' MD if MITT unsuccessful. Fullbore (contingent- if MITT unsuccessful) 6. MITT to 2500 psi. Slickline 7. Pull TTP. Operations 8. Put well in injection. DHD 9. Perform AOGCC witnessed MITIA to 2500 psi. 2 IIII IP i TREE= 6 X 7 CIW FLS VVELLFEAD= GRAY GEN 4 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= CAMERON 1 3-0 6A WHEN ON MI,WELL REQUIRES A SSSV WHEN ON ANL OKB ELEV= 78 BF ELEV= KOP= 3096' id —1600 --I TOP OF IA CANT(09/27/15) ,..e Max Angle= 51' 0 51%' Datum MD= 10606' 1784 1 5-1/2"SKR CMT RETAbER(10/15/15) *1 1 0 Datum ND"; ---8800'SS4 1800'-1806' _L1BG/CSG PLAICH(10/03/15) I .40 0 A :44 0 , , 0 2191' —5-1/2"CAMCO BAL-O NW,13=4 562" 1 i 13-3/8"CSG,72#,L-80,13=12341" — 2660' rd: 5-1/2'TEIG,17#,L-80,0 0232 bpf,ID=4.892- H 6684' 5-1/2-X 4-1/2"XO r--- --- TOP OF 4-1/2"TBG --1 6684 64A rl TOP OF r LNR H 6772* 0 9-518"WINDOW 8958'-6998' Minimum ID = 3.813" @ 10377' 4-112" HES X NIPPLE 1I 11Y272* --I4--17/2'CMT RETA IMER WISLDNG SLV(09/15/15) 10298'40296' TBG Ft#404(09/15/15) . [ TOP OF WHIPSTOCK j--1 6988" j G4,. _ _ _ _......- 10343' I—7"X 4-1/7 BAKER S-3 FKR,ID=3 as- „ , ... ,,, NIP 10377' —14-1/2-FES X ,0=381' I - Illik 10377' H4-1/2”PX Ft.UG(02/29/16) IMI r TOP OF CEMENT --I 10360' I 10399' 4-1/7'TUBING TAIL WLEG te.1 I 4•4. 4 10400' —8M3 TT LOGGED 02/11/98 WIPVIA0 tetat A Ato r 9-5/8"CSG,47#,L-80,ID=6.681" —F10762' I 4-1/2'TBG„12.6#,L-80,0,0152 bpf,ND=1958' —I 10399' 10966'CTM ASH 2 CBPS (11/13/15) N& PERFORATION SIMMARY ‘i I LOG.BHCS ON 01/11/98 44„, 41w ANGLEAT TCP FEW 10" 0 10617 .1104,14, 441140.1144. hbte Refer to Production C6 for historical perf data 7*LNR,26#,L-80,0 0383 bpf, --I 11069' ii4IM441V411; It4411141)* SIZE SIT INTERVAL Opn/Sqz SHOT SO7 13=6276' 3-318" 6 10612-10668 0 02/04/00 3-3/8* 6 10682-10707 0 02/04/00 3-3/8- 4 10745-10759 0 02/11/93 TO 11094' 3-3/8' 4 10774-10820 0 02/11/98 GATE REV BY COMVENTS ' DATE REV BY COMNENTS PRUDHOE BAY LINT 09/10/81 ' ORIGINAL COMPLETION t 12/07/15 SJW/JM)OA CENENTEO(11/14/15) WL 13-06A 02/11/98 WORKOVER ,,12/14/15'SJW/M)FISH MLLED 2X(BPS OH PERMT hb 197-2180 e. 03(05/01 SIS-M) FINAL 03/02/16 GS1.94)SET 4-1/2"PX PLUG(02(29/16)' AR No 50-029-20642-01 03111/02 RNITP CORRECTIONS t 03/16/16 R13/JPA) (HEE 00(03/13/16) SEC 13,T1ON,R14E,1643'FEL&80FVVL 10/28/15 NXWITLH BKR CMT RIM TAG(10/15/15) BP Exploration(Alaska) , 3 REA;Ely • MAR 22 ZO WELL LOG TRANSMITTAL#903085040 To: Alaska Oil and Gas Conservation Comm. March 11, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED /t3/201Co Anchorage,Alaska 99501 M.K.BENDER RE: WaterFlow Log with TMD3D and Temperature Log: 13-06A Run Date: 1/28/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 13-06AS ONE IL 3 Digital Log Image files 1 CD Rom 50-029-30642-01 WaterFlow Log with TMD3D and Temperature Log 1 Color Log-each 50-029-30642-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: val2-61-i-44) I5.ieltet r • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, February 03, 2016 10:12 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OIL;AK, OPS FS3 Facility OIL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Pettus, Whitney Subject: NOT OPERABLE:Injector 13-06A (PTD #1972180) Surface Safety Valve Function Test Failed All, Injector 13-06A(PTD#1972180) is due for an AOGCC MIT-IA. However,the well has been shut in and freeze protected after subsequently failing a surface safety valve function test. The well is reclassified as Not Operable until the safety valve system has been repaired and updated compliance testing can be obtained. The well has been added to the Quarterly Not Operable Injector Report. Please call with any questions or concerns. Thank you, Whitney Pettus $CAN4D MAY 1 9 2016 (Alternate:Kevin Parks) BP�All�aska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: 24 January 2016 01:46 To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK,RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; ers, Jessica; Dickerman, Eric; 'Regg, James B (DOA)'; Pettus, Whitney; Morrison, Spencer Subject: UNDER EVALUATION: Injector 13-06A (PTD #1972180)P,I,p7 Injection for Compliance Log All, Injector 13-06A(PTD# 1972180) is a WAG injector with a known production casing leak and known inner by outer annulus communication (IAxOA comm)that was mitigated by an IA and OA cement squeeze. sequently passing MIT-IA to 2500 psi was performed post squeeze on November 05, 2015 demonstrating two competent arriers to 1 i ! Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, January 23, 2016 4:47 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Regg,James B (DOA); Pettus,Whitney; Morrison, Spencer Subject: UNDER EVALUATION:Injector 13-06A (PTD #1972180) Place on Injection for Compliance Log Attachments: 13-06A aio4f-004 07-09-15.pdf All, Injector 13-06A(PTD# 1972180) is a WAG injector with a known production casing leak and known inner by outer annulus communication (IAxOA comm)that was mitigated by an IA and OA cement squeeze. A subsequently passing MIT-IA to 2500 psi was performed post squeeze on November 05, 2015 demonstrating two competent barriers to formation. The cement bond log run on October 02, 2015 following the IA squeeze confirmed top of cement as stipulated in sundry 315-264. In order for this well to be eligible for continued water only injection operation under Administrative Approval AIO 4F.004, and to demonstrate the successful repair of this well as per sundry, an initial water flow log will be run in order to verify that there is no significant flow behind pipe. At this time,the well is reclassified as Under Evaluation to facilitate compliance diagnostics. Please use caution when placing the well on injection as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: Monitor pressures daily 3. Electric Line: Once thermally stable, perform water flow log 4. Downhole Diagnostics: Perform updated AOGCC MIT-IA pending state review of water flow log 5. Well Integrity Engineer: Additional diagnostics as needed A copy of the approved Administrative Approval (pending successful repair) has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus WA'( 2 6 2015 (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 1 0 • C o a) \v u u ra 1 �� o d o r a s .9 ° Y a� a, O o-cf W a' - 1- c > C7 O@ co Y O� m a C ° h.- O A d l J0 e- N ,- e- in co O v E LE m I- 0 F O O Y , a � F- a) ig Nt c ro 2 ImOzz ° ° E Y rn IA WN • ON -O .- Q C V1 Z QNeN C (O N T > O_ — Q ° 0vE 0 > u a K F- I ° ° ° ° ° ° W J J J J J aWWWWWW > @ . 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Ou C C rz &i.n E v m U a., i g Q L a� 3 a` T Z 001 O CO N N .N- E a/ W _= a N ry J K (� O J E z y ra G a Q LO W n STATE OF ALASKA 41,LASKA OIL AND GAS CONSERVATION COMMI.V REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon D Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other: IA/OA Cement Squeeze m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 197-218 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20642-01-00 7. Property Designation(Lease Number): ADL 0028315 8. Well Name and Number: PBU 13-06A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11094 feet Plugs measured feet true vertical 9356 feet Junk measured 10966 feet DEC 15 2015 Effective Depth: measured 10984 feet Packer measured 10347 feet true vertical 9247 feet Packer true vertical 8617.68 feet A CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 81 20"91.5#H-40 31-111 31-111 1490 470 Surface 2627 13-3/8"72#L-80 30-2658 30-2658 4930 2670 Intermediate 6933 9-5/8"47#L-80 28-6961 28-5926 6870 4760 Production Liner 4297 7"26#L-80 6775-11072 5792-9334 7240 5410 Perforation Depth: Measured depth: 1800-1805 feet 10612-10668 feet 10682-10707 feet 10727-10741 feet 10756-10802 feet 12100-12470 True vertical depth: 1800-1805 feet 8880-8935 feet 8949-8973 feet 8993-9007 feet 9022-9067 feet 9049-9057 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): i 4 i k` i IA:1600'-10343'. OA:31'-2658'. Treatment descriptions including volumes used and final pressure: 9/27/15:295 Bbls 15.8 ppg Class G Cement,102 Bbls 60/40 Methanol/Water,10 Bbls PowerVis,31 Bbls Fresh Water,1415 psi. 10/30/15:96 Bbls 60/40 Methanol/Water,97 Bbls 1%Slick KCL,14 Bbls PowerVis,50 Bbls 9.8 Brine,163 Bbls 15.8 ppg Class G Cement,31 Bbls Fresh Water,4364 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 17570 80 2966 Subsequent to operation: Shut-In 20 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory ❑ Development ❑ Service lf Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG Ed 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: 315-264 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature (V — Phone +1 907 564 4424 err• Date 12/14/15 Form 10-404 Revised 5/2015 YT L (p /6 �/ U1 RBIJMS ��� �< Submit Original Only d 1/,-/. • • a) Q.00o0 N- (fl — co O p N V in co N- U o 0 0 0 0 0 i O M N- �t V ce) V O) co N N- V m CO N- N- CO CO CO V' CO N L() (N CO N N- N— CO O) M N- CO N Ln 67 LO CO CI i I I I H N CO r- O co O L() N CO CO N N- N N- LC) LC) a) W CNJ LO CO 8 CO N O CO S. N CO CO N- Ca) Ci CO 2 O Q OO CO N LC) CO si Cr) CO CO N CO N CO � 3 m a O ccoO O co i co O co J = J CO J = d *kN *kJ *kCO N .y V r N 00 N _ r U - c7 � NN O LCA I� N V) O Ill) 7 .c +' N- M N- N LCA 1:3) N M O) co co CO C) N CO N- J N CO d' CO CO W a)O — F- W U 0 W U a a Z Z Z W W m m OD ZjD UC/) Z =IHH • • U (0 0 O ^L U) C O 2 0. .c = • M co 0. 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KOP= 3096' >:",,'Max Angle= 51°@ 5196 1600 -{TOP OF IA CMT(09127/15} Datum M)= Datum ND= 10606' ;0, ite 1784H5-1/2"BKRCMTRETA�2(10/15/15) 8800'55 0' ��� 1$110'-1805 �T - BPUNCHGJCSG PUNCH(10/03115) X„,. A I 2191° -5.1/2'CAINCO BAL-O NP,ID"4.562" 13-3/8"CSG,72#,L-80,D=12.347" - 2660' :<, A IA • ► 5-1/2'TBG, 17#,L-80,0.0232 bpf,0=4.892" --[ 6684' r D ♦1 6684'1--{5-1/2"X 4-1/2"XO [TOP OF 4-1/2"TBG]--I 6684' .1 L , TOP OF 7"LM -i 6772' Minimum ID = 3.813" @ 10377' ► ► 9-5/8"WINDOW 6958'-6998' ► ► 4-1/2" HES X NIPPLE ► { ► 10272' ]-4-112"CMT RETAINER W/SLDNG SLV(09/15/15) l �� 10290'-10295' --1-113G PUNCH(09/15/15) TOP OF WHPSTOC K H 6988' ►' `` 10343' H7"X 4-1/2"BAKER S-3 PKR,D=3.88" '► 10377' --14-1/2"HES X tom',D=3.81" TOP OF CEalEii 10360' 1 MP 10399' -14-1/2'TUBING TAIL WLEG 1111111111111111111 ,11/11111/1111/111 10400' -I E-MD TT LOGGED 02/11/98 1111111111111111111 [ 9-5/8"CSG,47#,L-80,D=8.681" 1--1- 10752' 1 [ 4-112"TBG, 12.6#,L-80,0.0152 bpf,D=3.958" -IT 10399' 1 10966'CTM -F1Stt 2 CEPS MLLE DH (11/13/15) ,, PE FFORATION SUMMARY REF LOG:BRCS ON 01/11/98 ANGLE AT TCW PERF: 10"@ 10612' �;\�;\\ Note:Refer to Production CB for historical pert data 7"LNR,26#,L-80,0.0383 bpf. J 11069' \�\\�\\��` SIZE SPF INTERVAL n/ z SHOT SQZ L `\\\\\► OP Sq D=6.276' ;;,\► �3-3/8' 6 10612-10668 0 02/04/00 3-3/8" 6 10682- 10707 0 02/04/00 3-3/8" 4 10745- 10759 0 02/11/98 TD -[ 11094' 3-3/8' 4 10774-10820 0 02/11/98 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHHOE BAY UNIT 09/10/81 ORIGINAL COMPLETION 10/28/15 SIF/TLH PLUG/TBG PNCH(09/15/15) WELL: 13-06A 02/11/98 WOIR}COVE3R 10/28/15 CJSITLH PLUGRBG PNCH+C M1(10/03/15) PERMT No: 197-2180 03/05/01 SIS-IND FINAL 10/28/15 NXWITLH BKR CMT RTNR TAG(10/15/15) API No: 50-029-20642-01 03/11/02 RN'TP CORRECTIONS — 12/07/15 SJW/JMD'OA x(11/14/15) SEC 13,T10N,R14E 1643'FEL&80'FWL 09/08/15 GTW/JM.)PULLED PAN THUG(09/05/15 12/14/15 SJW/JI D FISH MLLED 2X IMPS DH BP Exploration(Alaska) ' N, OF Ty ce-�17j,-sem THE STATE Alaska Oil and Gas ti�,;—s� ��, of/\ T AAs Conservation Commission 1-11 ,ci,_:____.,_:.,__, . 1 . 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 OF ALAS Fax: 907.276 7542 0 I n www aogcc.alaska.gov RI\-- SCOV Aras Worthington Wells EngineerI BP Exploration(Alaska), Inc. 7 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-06A Sundry Number: 315-264 Dear Mr. Worthington: 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, l'°20 ,/). "%(-- Cathy P�oerster Chair DATED this 'Ciof June, 2015 Encl. • RECEIVED STATE OF ALASKA i\,1,AY 0 a 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION .,5 6 j 24. I LS APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280f 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool El Repair Well , a.t� Change Approved Program El Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ v�Time Extensi•n❑ Operations Shutdown❑ Re-enter Susp.Weill] Stimulate I=1 Alter Casing Other. Cf/ Of} \ " 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 197-218-0 • 3.Address: p �7 6.API Number. Stratigraphic ❑ service �, , P.O.Box 196612,Anchorage,AK 99519-6612 {c;u 50-029-20642-01-00 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU 13-06A Will planned perforations require a spacing exception? Yes ❑ No GI 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028315 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth ND(ft): Effective Depth MD(ft). Effective Depth ND(ft). Plugs(measured): Junk(measured): 11094 9356 • 10377 8648 10377 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 30.71 -110.71 30.71 -110.71 Surface 2627 13-3/8"72#L-80 30.21-2657.66 30.21-2657.57 4930 2670 Intermediate 6933 9-5/8"47#L-80 28 21-6961 41 28 21-5926.38 6870 4760 Production None None None None None None Liner 4297 7"26#L-80 • 6775.48-11072.41 5792.25-9334.41 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development ❑ Service El - 14.Estimated Date for -15.Well Status after proposed work: Commencing Operations: c, Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date' WINJ 0 - GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative. GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington Email Aras.Worthington@BP.Com Printed Name Aras Worthington Title Wells Engineer Signature Phone 5Q4-4102 Date Prepared by Garry Catron 564-4424 sh/moi3' COMMISSION USE ONLY Conditions of approval' Notify Commission so that a representative may witness Sundry Number: 3 I'S -2 LO 4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: vv-, ✓, i t i a f 7 t- ro ✓4 1 �vl f e c f�^o n 5 t b c c , to tic / << I��° �D b c a��;� ;` 'cam -fe)ri-o -.1/) c /.1. e-G p 'o r /u i ,7 J L-c fi wl . Spacing Exception Required? Yes ❑ No d Subsequent Form Required. /0 - 40L/ APPROVED BY // Approved by: � c/yJ COMMISSIONER THE COMMISSION Date: b _ S / vr_ 6,72.4/15- 4� � 0 84,64 Aid IL Form 10-403 Revised 1 /2 12 t' i lidfor 12 months from thdfite of approval. Submi `�rm and Attachments in Duplicate RBDMS� IIIN 1 n 7nlc Perforation Attachment ADL0028315 Well Date Perf Code MD Top MD Base TVD Top TVD Base 13-06A ' 2/4/00 APF 10612 10668 8880 8935 13-06A 2/4/00 ' APF 10682 10707 8949 8973 13-06A 2/11/98 PER 10727 10741 - 8993 9007 13-06A 2/11/98 PER 10756 10802 9022 9067 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF b -00 0 0 0 0 0 03 'Cr CO CO CO CO Co I J J J J J a) Q O 0 0 0 0 0 coI„ V Co O Co N o V Co N I- CO U ', 000000 L rn r v CO CO NY CO N O szt N- CO Co I- V co r— (13 Co 00 N CO CO `- N CO IC) t— N 6) CO Co Co N jU) 6) N co U) F- 0_ O CO CO 6) O N U') Q CO N I� CO I- N U) U) E a) E M N w N Q� I` O c\Im O © U) V CO co p 2 J 0 01'5 L0 co N CO Co N Cfl Co O co cc) O .4- co J Jco = J CO J N r 6) Oo NLtd CV N O 6) 2 L) „4- _c L C) I— U7 N O) O CO O) N — O C CO 6) N CO I- CO J CO V N CO Cfl W IT • W W U U p z z O � Z » > U Z W F- H Packers and SSV's Attachment ADL0028315 Well Facility Type _ MD Top Description TVD Top 13-06A - PACKER 6783 7" Baker ZXP Packer 5798 13-06A PACKER 10347 7 X 4.5 Baker Model S-3 Hydro-set Prod Packer 8618 i i � bP 13-06 OA Cement Squeeze Interventions Engineer: Aras Worthington (907) 564-4102 Pad Engineer: Irwin Chou (907) 564-5538 History 13-06A was drilled as part of the Pattern Reconfiguration Project targeting watered out 9-spot patterns and turning them into 5-spot WAG patterns in early 1998. The OA shoe was cemented and arctic packed by the rig via OA downsqueeze. The well was SI in Feb. 2014 due to the well developing an OA leak, where the pressure build up rate was not manageable by bleeds. It is also not eligible for an AA. The well has passed and MIT- T and MIT-OA, but failed an MITIA. A PPPOT-IC failed where it was determined that the secondary seals are bad, but the primary seals were holding. Since the IC was ruled out as a leak path, a LDL found a PC leak 238' ELMD. The plan forward is to do an OA cement squeeze to mitigate the PC leak. Current Status The well is currently classified as "Non Operable" by BP due to the OA repressurization issues which are deemed "not manageable by bleeds". The well is therefore currently shut-in until the OA is cemented fully and thus the repressurization issues remedied. Objective The objective of this job is to cement the OA and remedy the OA repressurization. The first step will be to cement the IA from the production packer up to above the surface casing shoe. The 9- 5/8" casing will then be penetrated with perforating charges through tubing. The arctic pack can then be circulated out of the OA and the OA subsequently circulated to cement. The goal is to have cement in the OA from the 13-5/8" casing shoe to surface. Procedural steps Slickline 1. Pull the tubing tail (PX) plug. E-Line 2. Set CBP just above production packer. MITT. 3. Tubing punch just above CBP. Coiled Tubing 4. Set cement retainer just above tubing punch. Sting into retainer and pump cement into IA from the production packer up to -2000' MD. Slickline 5. SCMT to log TOC in IA. E-Line 6. Set CBP @ -2000' MD. 7. Perforate through 5-1/2" tubing and 9-5/8" casing at -1800' MD Fullbore 8. Circulate arctic pack flush down tubing and up OA to remove arctic pack from OA. 9. Circulate cement down tubing and up OA to displace OA fully to cement. 10. Circulate add'I cement down tubing and up IA to get -200' of cement up IA above perforations. This will bring the new IA cement top to -1600' MD. 11. WOC - 5 days. MITIA to 2500 psi. Coiled Tubing 12. Mill out cement in tubing and upper CBP. 13. Mill out cement retainer. MITT to 2500 psi. Mill out bottom CBP. Push remnants to TD. 2 TREE-. GRAY G134 4 WE:LU15A()= GRAY SAFETY NOTES: H2S READINGS AVERAGE 126 ppm _______ 13-06A ACIlL1TDR= OTISWHEN ON Ni.WELL REQUIRES A SSSV WHEN ON '0K13.13.E1/_ 78' Ml. BF-Bpi/_ _7 ' KOP=, 3096 �) ' 2191' H 5-112-CA MOO RAI•0 NP.I)•4 567" MuAngle= 51 0 5196' �`3j,syi U Gahm k0= 10606 Datum ND= 88IXY SS + s. 13-318•CSG,72*,t-60,D=12.34r 266W OP �r L•fir i• (Jt 1 Minimum ID = 3.813" @ 1037T <' 0 e� • 4-112" HES X NIPPLE 19-11TSG, 176,1-80,0 0232 bpf,D=4.892'i 1 7 NW "S-117"X 4-1/r X0 I [TOP OF 4-112•TBG 06M C6 t TOP OF r LFR —i 6772' / /n D 9-518"W1NODW 69`113'-6998' I TOP OF VNlki3s'rdeici Aa" it - 7►,, 10343' T X 4-1/2"BAKER S-3 RCH,ID=388" 1 ,,,4 10377' —I4-1/2"HES X Fp,11:1=3.81" •, .�`. 10377' j--I4-1/2'PC PLUG(�i07114) I TOP OF CEMENT H 10360 L 1 ansa• f 4 112"Ti.Elt'1C;TA L Y&S I ��r�r�r�r�r�r�r�r�� !r.rr0004r.01 ( 10400 aLO n LOGc�®02/1 t+>is 00404000;+�Ir1 44r4r8 884/84448 I— 9-5/8'CSG,47N,1-80.D=8.881' I- 107152' 4-1.2"TBG,12.88,L-80,0.0152 bp(.D=3.958' — 10399" PERORATION SUMMARY REF LOG:BE-CS ON 01/11/98 "t li ANGLE AT TOP PERE 10"6 10617 +t,.~ R Note_meter to Ffioducbon EJB For historical pert data 1'LN11,2811,1-80,0_0383 bpi, `.--i 11069' 416011 11116 SIZE SPF INTERVAL OpnlSgz SNOT SC]Z D=6.2.76' Lj *\ ► 3-3/8' 6 10612-10668 0 02/04/00 T' 3-318'" 6 10682-10/0 r 0 02/04400 • 3-3/8- 4 10745- 10759 0 02/11/98 ! TO ti t 11094• 3-318' 4 10774-10820 0 02/11/98 i GATE REN/BY I COMIC:NTS DATE REV BY COAIABd'fS PRUDHOE BAY UNIT 09/10/81 OF1IGI4AL,CX)8t1J ZION 02/1004 F1NCT/JM.) SET PX FL.UG(02107/14) WE 3.L: 13-06A 02111/96 i WORFCOVER PEFMT NO 197.2180 11/19100 S&JH CONVERTED TO CANVAS API Pb: 50-02920642 01 03/05/01 SIS-1•U ANAL SFC`13,T10N,R14E 1643'Fa&&r FWt 1 , 03/11/02, FIPTP CORRECTIONS BP Exploration(Alaska) 3 f ¼ -1- 2\'' 2-561 2. WELLLOG DATA LOGGED 5 l /2015 TRANSMI7TA / M.K.BENDER RECEIVED PROACTIVE DIAgINOSTIC SERVICES, INC. APR092015 AOGCC To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 sCAKD MA 0 7 nil, 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 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 17-Jan-15 13-06A BL/ CD 50-029-20642-01 2) Signed : 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: PDSANCHORAGEaMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFdes\Templates\Distnbution\TransmittalSheets\BP_Transmit docx XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial They are available in the original file and viewable by direct inspection. //~- 2/~ File Number of Well History File PAGES TO DELETE 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 n Other scanning Project. Complete COMMENTS: Scanned by: ~vedy Mildred Darethaowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si MEMORANDUM To: Jim Regg t~ 7 P.I. Supervisor ~C~~ (~~:0 FROM: John Crisp Petroleum Lrspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 09, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC ] 3-06A PRUDHOE BAY UNIT 13-06A Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv J Comm Well Name: PRUDHOE BAY UNIT 13-06A Insp Num: mitJCr100708213609 Rel Insp Num: API Well Number: 50-029-20642-01-00 Permit Number: 197-218-0 Inspector Name: John Crisp Inspection Date: 7/4/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-o6A ~ Type Inj. w TVD 8614 IA 470 2330 P.T.D 197z1so. TypeTest SPT Test psi 2153 / OA slo 6so Interval 4YRTST per, F .~ Tubing j 660 660 NOtes: 3 bbls pumpe for test. Glan nuts leaking on well head. Stopped test, bled off for repair. n r;! r` i ~i;t_# 1;.. \ 1}. Friday, July 09, 2010 Page 1 of 1 i ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission n DATE: Friday, .luly 09, 2010 To: Jim Regg K P.I. Supervisor ~ ~ ~ ~ll~t% SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-O6A FROM: John Crisp PRUDHOE BAY UNIT 13-O6A Petroleum Inspector Src: Inspector N(1N-~(lNFinF.NTiAL Reviewed By~ P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UNIT 13-06A API Well Number: 50-029-20642-01-00 Insp Num: mitJCr100708213918 Permit Number: 197-218-0 Rel Insp Num: Inspector Name: John Crisp Inspection Date: 7/4/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-o6A 'Type Inj. w TVD~ 8614 ~ ~ IA 440 2320 2300 2300 ' P.T.D 1972180 TypeTeSt SPT ~ Test psi 2153 ~ QA 520 700 700 700 Interval aYRTST p/F P ~ Tubing bbo bbo bbo bbo Notes: 3 bbls pumped for test. Re-test after well head gland nuts were tightened. r ~:,, Friday, July 09, 2010 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~~ Email to:jim.regg~alaska.gov; phcebe.brooks@alaska_gov; tom.maunder~alaska.gov; doa.aogcc.prudhce.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS-13 DATE: 7/4!10 OPERATOR REP: Jerry Murphy AOGCC REP: John Crisp Packer D Pretest Initial 15 Min. 30 Min_ Well 13-06A T I '. W TVD 8,614' T 660 660 660 660 Interval 4 P.T.D. 1972180 T test P Test 2153.5 440 2,320 2,300 2,300 P/F P Notes: MIT-IA to 2300 psi fa 4 year UIC OA 520 700 700 700 Pum 3 bbls MEOH to achieve test Well 13-16 T In'. W TVD 8,456` T 880 880 880 880 Interval 4 P.T.D. 1821480 T test P Test 2114 370 2,360 2,345 2,340 P/F P Notes: MIT-IA to 2300 psi for 4 year UIC OA 530 720 720 710 Pum 3 bbls MEOH to achieve test ' Well T In'. TVD T Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test P/F Notes: OA TYPE INJ Codes TYPE TEST Codes 'C ~ ~ 1 ~` D =Drilling Waste M =Annulus Monitoring ~ ~"+» ~~ v ~~ ~'~` ~~ ~') t~ ~. ~~~ ~ G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Arwmaly Survey W =Water D =Differential Ternper~ure Test ~a ugh INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 13.061316 07-0410.x1s R,~~c~ v LÛ AUG 0 8 2006 Schlumbepger .~~ Oil & Gas Cons. C~ NO. 3883 .A.ncnorage "'-¡. i.". Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth (j I~ /1 (:17- -d { "8' Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WI! J # D e ob Log escrlption Date BL Color CD NK-43 1121138ö PRuu t"KuFILt: W/UEf' I 04/02/06 1 NK-22A 10568415 PROD PROFILE W/DEFT 02/26/03 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 SBHP 12/02/05 1 X-15A 11212877 USIT 07/18/06 1 J-01 B 11511430 US IT 07/24/06 1 15-12A 11221595 US IT 07/25/06 1 Z-14B 11217268 USIT 07/29/06 1 S-400 10987564 CH EDIT PDC-GR OF USIT 01/26/06 1 D-03A 11217269 USIT 07/31/06 1 05-28A 11217267 USIT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 A TIN: Beth 08/01/06 . . Sc~luIIIbergep lL-f 1- - é) I~ UT0..- NO. 3880 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth , 't>.. ~'''jr..l~~ "~:~~~.~j' <.;:'~¡.~::' i~ ~.'; Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~ Well Job# Loa DescriDtion Date BL Color CD 15-12A 11211420 RST GRAVEL PAcK 06/25106 1 17-08 11211509 IN"c\, . lvi'll PROFILe 06/24/0ti 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 P2-01 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-08 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16-04A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06 . 1 17-09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC-07 N/A SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 b-51 11212873 USIT 06/28/06 1 04-31 11217264 USIT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI-07 10703937 MDT 10/13/03 1 02-16B 11209601 MCNL 04/25/06 1 1 L2-'18A 11217234 MCNL 04/06/06 1 1 L5-09 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 07/19/06 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 0 v í{ '7/ ¡ , P.I. Supervisor \ ''-JoY {' . \--(;;/')",0 DATE: Wednesday, July 05, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-06A PRUDHOE BAY UNIT 13-06A \ 0{1'd-- \ ~ FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By-,- P.I. Suprv ~\3f2- Comm Well Name: PRUDHOE BAY UNIT 13-06A API Well Number 50-029-20642-01-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060628131439 Permit Number: 197-218-0 Inspection Date: 6/28/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 13-06A ¡Type Inj. : w TVD 8614 , IA 40 i 2250 2200 i 2190 I P.T. I 1972180 ITypeTest i SPT Test psi ! 2153.5 r OA 120 340 340 i 340 ! , I 4YRTST P ;/ Tubing 620 I 620 620 T620 I Interval PIF ¡ I Notes NON-CONFIDENTIAL Wednesday, July 05, 2006 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylorcdi' Chairman DATE' May 20, 2002 FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX DS 13 PBU Prudhoe Bay WellI 13-06A P.T.D.I 197-218 Notes: Welll 13-16 P.T.D.I 182-148 Notes: Packer Depth Type testI P I Test psiI 2154 ,, , Pretest Initial 15 Min. 30 Min. 'ubing I 1050 I 1050 I 1050 ! 1050 Ilntervall 4 ',asingI 500 J'2420 ! 2400 'j' 2~,00'.1 P/F I __P Type testJ P J TestpsiJ 2114 ICasingI 50 J 2280 ! 22'50 i" 2250 I P/F J P We,,! 3-32A I Type,nj.I S I I T bingl ,00 i .'0o I' 40o l,.terv ,l , P.T.D.I 201-235 Type testI P I Test psiI 2137 I Casing I 360 ! 2270 !" 2220 '1' 2220' I "P)F I -P Notes' Initial test 3ost coil tubing drilling side track WellJ 13-35 Type lnj. J S i T.V.D. 18061 I Tubing 11350 11350 I 1200 i' 1200 l lnte~all 4 P.T.D.I 194'041 Type test! P I Testpsii 2015 lCasingI 400 I 2320 I 2280' '! 2'~0' .I P)F J ~. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test' M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs Drill Site 13 and wimessed the 4-year MIT on wells 13-06A, 13-16, 13-35 and thi initial MIT on well 13-32A. The pretest robing and'casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 4 wells demonstrating good mechanical integrity. M.I.T.'s performed' 4 Number of Failures: 0 Attachments' Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. MIT PBU DS 13 5-20-02 CS.xis 6/3/02 THE MATERIAL UNDER THIS COVER HAs BEEN MICROFILMED ON OR BEFORE M PL A T T H E IA L IS ~ .AR E U W N D E R K E R C:LOEI~IFILM.DOC 197~218_0 MD 11094 PRuDHOE B~Y'~ ......... i~0S~ ............................. ~0~ '0'~'~'i-oi ......... 5kRc6 ........ TVD 09356 EOSmmpletion Date: ~'2/11/98 Completed Status: WAGIN Current: T Name Interval Sent Received T/C/D D 8232 ~',.~eb~'/ SPERRY GR OH 2/4/98 2/4/98 D 8233 ~ SPERRY GR PB1 OH 2/4/98 2/4/98 . L BHPROF t..PII~AL 6980-10956 OH 2 3/10/98 3/13/98 L BHCS t..,J:~AL 6980-10926 OH 3/10/98 3/13/98 L INJP-SPINFFEM/ ~ PRES 10660-10872 10/18/99 CH 5 10/28/99 11/4/99 L NGP-MD "~q~L' 8507-10520 OH 2/11/98 2/11/98 D L NGP-TVD ~q'~L 7113-8788 OH 2/11/98 2/11/98 D L PEX3DD/CN ~AL 6980-10956 OH 3/10/98 3/13/98 L PEX-AIT F~I;N~L 6980-10968 OH 3/10/98 3/13/98 L PEX-CN ~,F..~qAL 6980-10945 OH 3/10/98 3/13/98 L SSTVD ~,,IAL 6980-10968 OH 3/10/98 3/13/98 L USIT/CMT ~ BL(C) 10970 CH 5 3/8/99 3/11/99 R MWD SRVY FINAL 0~254111-11044.18 OH 3/17/98 3/18/98 R MWD SRVZ t.~"~R'RY 6896.-10628. PB1 OH 1/29/98 2/4/98 D R MWD SRVZ --SPERRY 8490.29-10458. OH 1/29/98 2/4/98 D T 8351 j SCHLUM PEX-AIT/BHC OH 3/10/98 3/13/98 Daily Well Ops ~f//q~ -- ///~/c~ Are Dry Ditch Samples Required? yes ~_____~nd Received? 6'es'""atr Was the well cored? yes no.~~. Analysis Description Rece~~-' Sample"JeVg'''~ Comments: Thursday, February 03, 2000 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perlorate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 74 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3632' FNL, 5198' FEL, Sec. 13, T1 ON, R14E, UM (asp's 687305, 5931713) 13-06Ai At top of productive interval 9. Permit number / approval number 4256' FNL, 1222' FEL, Sec. 13, T10N, R14E, UM (asp's 691296, 5931192) 197-218 At effective depth 10. APl number 50-029-20642-01 At total depth 11. Field / Pool 4269' FNL, 1151' FEL, Sec. 13, T1 ON, R14E, UM (asp's 691367, 5931180) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11094 feet Plugs (measured) Top of Sand Plug @ 10978' MD (1/26/2000). true vertical 9356 feet Effective depth: measured 10978 feet Junk (measured) true vertical 9241 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 10' 20" 300 Sx PF 1 10' 110' Surface 2586' 13-3/8" 2750 sx Fondu & 400 PFC 2660' 2660' Production 6884' 9-5/8" 500 Sx Class G & 300 SX PFC 6958' 5924' Liner 4297' 7" 944 sx C~ass G 11069' 9331' Perforation depth: measured 10612'- 10668'; 10682'- 10707'; 10745'- 10759'; 10774'- 10820'. ~ ~ ~"'-'i, ~ .... true vertical 8880' - 8935'; 8949' - 8973'; 9011' - 9025'; 9039' - 9085'. 7",26#,L-80Tbg @ 23'MD; 5-1/2", 17#, L-80Tbg @ 6684'MD; 4-1/2", 12.6#, L-80Tbg @,RECEIVED Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7"X 4-1/2" BAKER S-3 PACKER @ 10343' MD. 0 8 2000 5-1/2" CAMCO BAL-O SSSV @ 2191' MD. 13. Stimulation or cement squeeze summary ,~ Oil & Gas Coas. Comrnis n Intervals treated (measured) (see attached) AJ~l~lOr~ Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 5754 769 Subsequent to operation - - 5651 809 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil __ Gas __ Suspended m Service ~(WAG).~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ..~,.~,~ ~ ~.~ Title ARCO EngineeringSupervisor Date Erin Oba ' Prepared by Paul Rauf 263-4990 _ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 13-06Ai DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 1/26/2000: 2/04/2000: RIH & tagged PBTD @ 10978' MD. MIRU ELU. PT'd equip to 3000 psi. RIH w/perforating guns & shot 81' of Add Perforations located @: 10612' - 10688' MD (Zone 4) Reference Log: BHCS 1/11/1998. 10682' - 10707' MD (Zone 4) Used 3-3/8" carriers & all shots @ 6 SPF, random orientation, 60° phasing, & balanced pressure. POOH w/guns. ASF. RD. Returned well to WAG injection & obtained.valid injection data. Initial service was in produced water service. Page 1 Schlumberger NO. 12891 10/28/99 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-32 PERFORATING RECORD 991023 I 1 D.S. 1-30 PSP-LEAK DETECTION LOG 991022 I 1 D.S. 2-19 PRODUCTION PROFILE 991023 I 1 D.S. 13-6A ~ c__. INJECTION PROFILE 991018 I 1 D.S. 11-22A 99368 RST -~. ~ ~L~..~ 990906 I I 1 D.S. 14-24 99377 EST .-~ c~[~'Z... 990901 I I I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Th~~~ .. STATE OF ALASKA ._ .... ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well i--I Oil [] Gas [] Suspended I--IAbandoned [~ Service Water & Gas Injector 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-218 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 .- 50-029-20642-01 4. Location of well at surface ' ~ ~ 9. Unit or Lease Name 1643' NSL, 5199' WEb, SEC. 13, T10N, R14E.. UM i' ............ J ",~:~ ::Ti~i..;- ........ ..;..,---~ Prudhoe Bay Unit ~2L. ~-~...:~.._ !;..~mf~. 10. Well Number At top of productive interval i ~//~, i~ '~~..... 11. Field and Pool 1022' NSL, 1222' WEb, SEC. 13, T10N, R14E, UM - 13-06Ai At t°tal depth i: ~"7:' ;!i ' 1009' NSL, 1150' WEL, SEC. 13, T10N, R14E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation~nd Serial No. Pool KBE = 74'I ADL 028315 12. Date Spudded12/14/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re 1la' N°' °f c°mpleti°nsl/10/98 2/11/98 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11094 9356 FTI 10984 9247 FTI [~Yes []NoI (Nipple) 2184' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, DIR, RES/ALT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES, Sonic, Numar, USlT, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 32" 300 sx Permafrost cement 13-3/8" 72# L-80 Surface 2660' 17-1/2" 2750 sx Fondu, 400 sx Permafrost 'C' 9-5/8" 47# L-80 / S00-95 Surface 6958' 12-1/4' 500 sx Class 'G', 300 sx Permafrost 'C' 7" 26# L-80 6786' 11069' 8-1/2" 944 sx Class 'G' 124. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.375" Gun Diameter, 4 spf 5-1/2", 17#, L-80 6684' MD TVD MD TVD 4-1/2", 12.6#, L-80 6684' - 10399' 10343' 10745' - 10759' 9011' - 9024' 10774' - 10820' 9039' - 9085' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 140 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) February 28, 1998I Water & Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE IGAS-OIL RATIO TEST PERIOD 1 Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~,~a$~(a 0JJ & 8as C0rJs. Comi~]issi0n Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. ~ ....... Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 10523' 8792' Shublik 10545' 8813' Sadlerochit 10622' 8889' 31. List of Attachments Summary of Daily Drilling Re~ts, Su/~./ey/s/2 ;32. I hereby certify that the for~/~ing is ,~ue/~n.d/correct to the best of my knowledge Signed Tim.A_.B_ur_ns. ~~'rk ~,'¢~~ Title Senior DrillingEngineer Date 13. u5^i 97~218 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 CORE LABORATORIES CORE ANALYSIS STUDY Prudhoe Bay 13-06A Well Alaska Performed for: Arco Alaska, Inc. 700 {~ STREET ANCHORAGE, ALASKA 99510 April 29, 2OOO Performed by: Core Laboratories, Inc. Advanced Technology Center Rock Properties Laboratory 1875 Monetary Drive Carrollton, Texas 75006 File: DAL-97369 The analytical results or interpretations contained in this report are based upon information and material supplied by the client for whose exclusive and confidential use this report has been made. The analytical results, opinions or interpretations expressed represent the best judsment of Core Laboratories. Core Laboratories, however, makes no warranty or representations, express or implied, of any type and expressly disclaims same to the productivity, proper operations or profitableness of any oil, £as, coal, or other mineral property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced in whole or in part without the written consent of Core Laboratories. PETROLEUM SERVICES April 29, 2000 Mr. Patrick McGuire ARCO Alaska, Inc. 700 G Street Anchorage, Alaska 99510 Subject: Core Analysis Study Prudhoe Bay 13-06A Well File: DAL-97369 Dear Mr. McGuire: Core Laboratories' Advanced Technology Center in Carrollton (Dallas), Texas is pleased to present the final report for a core analysis study performed on 300 feet of core material recovered from the referenced well. Preliminary information was provided to the client as it became available. A project summary, description of laboratory procedures, and presentation of results are provided within. Fifteen copies of this final report have been issued. We appreciate this opportunity to have been of service to Arco Alaska, Inc. Please contact us at (972) 466-2673 if you should have any questions regarding this report, or if we may be of further assistance. Sincerely yours, Paul R. Martin '~'~' Petrophysics Supervisor Dallas Advanced Technology Center 15 copies: addressee Core Laboratories, Inc. 1875 Monetary Lane, Carrollton, Texas 75006-7012, (972) 466-2673, Fax (972) 323-3930, E-mail @corelabusa.com Arco Alaska, Inc. File: DAL-97369 PROJECT PARTICIPANTS Basic Properties Dean-Stark Fluid Saturations: Porosity and Permeability Measurements: Project Coordination, Data Evaluation, and Report Preparation: Final Report Review: jacque R. Brown Lynn M. Antwine Stephen M. Hoff Paul R. Martin Gary Potter Core Laboratories Arco Alaska, Inc. File: DAL-97369 TABLE OF CONTENTS SECTION 1: PROJECT SUMMARY SECTION 2: LABORATORY PROCEDURES SECTION 3: HORIZONTAL PLUG AND DEAN-STARK SATURATIONS DATA 800 & 3500 psi Net Overburden SECTION 4: VERTICAL PLUG DATA 800 & 3500 psi Net Overburden SECTION 5: GRAIN DENSITY Core Laboratories SECTION 1 PROJECT SUMMARY Core Laboratories Arco Alaska, Inc. File: DAL-97569 PROJECT SUMMARY Core Reception and Processing-Carrollton, Texas The core processing was performed according to a procedural protocol outlined by Arco Alaska, Inc (attached). 200 horizontal and 192 vertical core plugs were cut for routine core properties analysis. Procedures followed are listed in the Laboratory Program section of this report. Laboratory Program Routine plug samples were analyzed in strict accordance with Arco Alaska's protocol described in the laboratory procedures. The horizontal and vertical plugs were subjected to Dean-Stark saturation determination, tracer analysis, cleaning and drying, permeability, porosity and grain density measurements. Laboratory procedures are described in Section 2 and test results are presented in Sections 3 through 5. A summary of sample selection is listed below: ROUTINE HORIZONTAL PLUGS ROUTINE VERTICAL PLUGS 200 192 SPECIAL ROUTINE HORIZONTAL PLUGS Preliminary data results were provided to the client on a regular basis. A preliminary core analysis report provided including all horizontal plug permeability and porosity, grain density, saturation data. - 1-1 Core Laboratories Arco Alaska, Inc. File: DAL-97369 SECTION 2 LABORATORY PROCEDURES Core Laboratories Arco Alaska, Inc. File: DAL-97369 LABORATORY PROCEDURES Laboratory analytical and quality control procedures used dudng the analysis of the core from the Prudhoe Bay 13-06 well followed the procedural guidelines set forth by Arco Alaska, Inc. Any modifications or additions to the wdtten protocol were by request or by approval of Arco Alaska, Inc. or AEPT Piano. Dean-Stark Analysis Each Dean-Stark flask and associated glassware were cleaned and dried before use. The condenser, core chamber and flask were rinsed five times with 20cc of fresh reagent grade toluene before adding toluene to the apparatus for pre-boiling. The sidearm was checked for water and pure toluene was transferred from sidearm to flask, the sidearm was then dded. Each core plug sample was weighed to 0.001 g, placed in a predried and relabeled glass thimble and weighed again. Each plug and thimble was then loaded into the Dean-Stark apparatus. The system was sealed with Teflon® tape to prevent leakage and capped with desiccant to prevent the introduction of condensed atmospheric water. Water volume in each Dean-Stark receiving tube was monitored during the toluene refluxing until stabilization. A wire was used to swab off any water droplets from the neck of the condenser. A record of time and water volumes was kept for each sample. Dean Stark extraction time for each sample was approximately 48 hours. After extraction, the flask'and contents were removed. The toluene in the side arm was removed and added to the flask. The water recovered in the side arm was removed and poured into a storage bottle, sealed, and labeled for D20 tracer analysis. After the Dean Stark process the plugs2 were loaded into individual extraction units for complete hydrocarbon and salt removal using chloroform-methanol azeotrope. The plugs remained in individual units for a minimum of one week followed by a minimum of 24 hours with fresh azeotrope to Verify that they were completely clean3. Sample Drying Each core plug and thimble was dded in a convection oven at 240°F for four hours, followed by 24 hours drying in a vacuum oven at 240°F. Sample weights were monitored approximately every 4 to 24 hours until weight stabilization (+/- .01 g) was achieved. After drying, each plug and thimble was allowed to cool in a desiccator and then weighed to 0.001 g. Each plug was removed from its thimble, brushed to remove residual dust, labeled and reweighed. Grain Volume Determination Grain volumes were measured using the Boyle's law AutoporosimeterTM which was calibrated and checked with a known volume stainless steel disk and quartz check plug (2.65 g/cc). Plug samples were For the upper interval: 10,523 to 10,624.1. From the upper interval For the rest of the core, only chloroform was used as the solvent since the plugs were to be crushed and extracted to recover the bromide tracer. Core Laboratories Arco Alaska, Inc. File: DAL-97369 kept in a desiccator until ready for grain volume measurement. After every five samples, a steel check disk was measured to ensure correct equipment operation. Equipment recalibration was performed a minimum of twice a day or as needed. Grain densities (gm/cc) were calculated using the dry sample weight (gm) and grain volume data (cc). Grain Density Grain densities were calculated from observed data using the formula: GD = DW GV where: DW = Dry weight, gm GV = Grain volume, cc Grain volumes and grain densities are reported on the routine core properties summary in Section 5. Plug Porosity and Permeability Measurements by CMS-300TM Horizontal and vertical plug samples were measured for permeability and porosity by the CMS-300 at 800 and 3500 psi net overburden. Before each group of samples was run, a standard system leak test was performed to ensure correct equipment operation. Calibrated, known volume check cylinders were run before and with each carousel suite of samples. The Klinkenberg (slip corrected) permeability for each plug sample was determined as a function of pressure decay (helium blow-down). A reference cell of known volume charged the sample with helium. A downstream valve vented the sample to atmosphere, and the change in pressure with time was monitored. The multiple flow regime data allowed the determination of Klinkenberg permeability of the sample, a calculated air permeability, along with parameters helium slip factor (b) and the inertial resistance factor (1~) beta. Any plug with permeability to air of 3000 md or more was remeasured using the Autopermeameter (a steady-state device), which has greater accuracy in measuring higher permeability samples, and the Autopermeameter data was reported. Porosity for each plug sample was calculated using Boyle's law by the CMS-300TM with grain volume and pore volume by: 2~ = (PV · 100) / (PV + GV) where: ~ = PV = GV = Porosity, percent Pore volume at net confining pressure, cc Grain volume, cc For the upper interval: 10,523 to 10,624.1. From the upper interval For the rest of the core, only chloroform was used as the solvent since the plugs were to be crushed and extracted to recover the bromide tracer. 2-2 Core Laboratories Arco Alaska, Inc. File: DAL-97369 Data was downloaded to diskette, imported to the core analysis report software, and preliminary data printouts were provided to the client regularly. Samples unsuitable for CMS-300TM testing were subjected to ambient condition porosity and profile (probe) permeability testing and are noted in the tabular data. Fluid Saturation Calculations The observed Dean Stark weights and produced water volumes were combined with the measured pore volume data to calculate in situ oil and water saturations for each sample. A summary of all measured and calculated data for the horizontal plugs is presented in tabular and graphical formats in Section 3; vertical plug data appear in Section 4. Water saturation is calculated from the volume of water recovered during the Dean Stark distillation. The water volume is not corrected for salt content and is expressed at standard conditions (1 atmosphere and 60°F. The oil saturation is dedved from the weight loss during the Dean Stark distillation and subsequent solvent cleaning adjusted for the mass of water recovered. An oil density of 0.790 gm/mi is used in the oil saturation calculation unless an alternative value is provided by the client. For the 13-06 core an oil density value of 0.898 gm/mi was provided and used in the calculation of oil saturation. In the D-06A routine core analysis report released earlier, the 0.790 gm/mi value was used in oil saturation calculations. Any comparison of oil saturations in these two cores should incorporate this oil density difference in the saturation calculation. Tracers were added to the drilling fluid to monitor the invasion of the core by the drilling fluids. D20 was used in the first batches of drilling mud. The Dean Stark water removed from the side arm and the drilling fluid filtrate were analyzed for Deuterium Oxide content. Knowledge of these D20 concentrations allowed calculation of filtrate invasion in plugs ranging in depth from 10523.1 feet to 10624.1 feet. The 920 was used up at this point and a Sodium Bromide tracer was added to the drilling fluid from 10626.1 feet to 10821.7 feet. Bromide analyses were done on the leach water supemate from the crushed, dried core plugs and the ddlling mud filtrate. Knowledge of these bromide concentrations allowed calculation of filtrate invasion in the core plugs. Filtrate saturation can be calculated using the formulas listed below: The filtrate volume must first be calculated using the formula below: Or Filtrate fraction = D20 sample Filtrate fraction = Br - sample - D20 background / D20 mud -D20 background Br' background / Br' mud - Bt' background Core Laboratories 2-3 Arco Alaska, Inc. File: DAL-97369 Once the filtrate fraction is determined, a filtrate corrected water saturation can be calculated using the formula below: Filtrate corrected Water Saturation = Original water saturation x ( 1 - Filtrate fraction) And the filtrate saturation (as reported on the tables) can be determined using the formula below: Filtrate saturation = Original water saturation - Filtrated Corrected Saturation Core Laboratories ARCO Alaska, Inc. File: DAL-97369 Section 3 HORIZONTAL PLUG and DEAN-STARK SATURATION DATA Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Horizontal Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Water Filtrate Oil Total Sample millidarc¥s Porosity, Volume, Saturation, Saturation, Saturation, Saturation, Grain Dry Grain Sample Depth, Klinkenber~l I to Air percent cc percent PV percent PV percent PV percent PV Volume, Weight, Density, Number feet 800 psi I 3500 psiI 800 psi I 3500 psi 800 psi13500 psi, 800 psi13500 psi 800 psi13500 psi 3500 psi 800 psi13500 psi 800 psi13500 ps~ cc ~lrams ~lm/cc lA 10523.10 0.020 0.0031 0.042 2A' 10524.10 0.015 0.0032 0.030 3A 10525.10 0.015 0.0025 0.033 4A 10526.10 18.3 17.0 20.8 5A 10527.10 8.40 7.46 9.95 6A 10528.10 14.0 13.1 16.1 7A 10529.10 12.6 11.7 14.5 8A 10530.10 16.7 15.8 18.9 9A 10531.10 11.4 10.6 13.3 10A 10532.10 22.5 21.0 25.3 11A 10533.10 18.9 17.6 21.4 12A 10534.10 12.3 11.4 14.2 13A 10535.10 10.3 9.61 12.0 14A 10536.10 9.32 8.62 10.9 15A 10537.10 6.97 6.48 8.24 16A 10538.10 5.62 5.18 6.76 17A 10539.10 2.98 2.74 3.70 18A 10540.10 4.68 4.36 5.62 19A 10541.10 4.54 4.30 5.41 20A 10624,10 7.25 4.19 8.22 21A 10625.10 58.8 55.4 63.3 22A 10626.10 83.2 78.2 88.5 23A 10627,10 137. 130. 144. 24A 10628.20 123. 116. 129. 25A 10629.10 107. 101. 113. 26A 10630.60 41.7 38.9 46.3 27A 10631.10 441. 408. 447. 28A 10632.10 705. 668. 711. 29A 10633.30 544. 512. 550, 30A 10634.30 57.1 53.2 62.2 31A 10635.10 176. 165. 184. 0.010 8.7 7.8 3.776 3.376 58.8 65.8 0.0099 8.6 7.6 3.777 3.283 28.4 32.7 0.0090 8.3 7.5 3.590 3.216 60.7 67,8 19.3 20.4 19.8 8.904 8.576 43.4 45.1 8.83 19.5 18.8 8.364 8.009 41,7 43.6 15.1 19.3 18.7 8.409 8.107 35.9 37,3 13.5 19.0 18.4 8.157 7.835 36.5 38.0 17.8 19.0 18.5 8.353 8.084 31.1 32.1 12.4 19.1 18.6 8.369 8.072 31.6 32.8 23.6 20.3 19.6 8.678 8.316 29.5 30.8 19.9 20.4 19.7 8.956 8.600 30.6 31.9 13.2 19.4 18.8 8.404 8.083 33.9 35.3 11.2 19.7 18.8 8.476 8.018 33.1 35.0 10.1 19.3 18.7 8.399 8.085 38.4 39.9 7.63 18.3 17.7 7.824 7.494 36.5 38.1 6.23 18.4 17.8 7.932 7.618 36.7 38.2 3.39 16.7 16.2 7.271 7.002 40.5 42.1 5.23 17.3 16.7 7.546 7.222 34.5 36.1 5.11 16.2 15.6 7.074 6,771 44.2 46.2 4.88 13.1 12.2 5.638 5.180 40.7 44.3 59.7 83.2 136. 122. 107. 43.3 415. 671. 519. 58.0 173. 20.1 19.4 8.750 8.404 39.4 41.0 21.9 21,1 9.231 8.769 41.8 44.0 23.2 22.4 10.121 9.711 43.7 45.5 22.2 21.3 9.395 8.938 35.0 36.7 22.9 22.1 9.875 9.423 40.9 42.8 22.7 21,9 9.834 9.362 46.2 48.5 25.6 24.7 11.059 10.523 47.0 49.4 27.2 26.4 11.686 11.240 46,8 48.7 24.3 23.7 10.458 10.108 40.1 41.5 20.9 20.1 8.964 8.550 42.1 44.2 22.8 21.9 9.862 9.396 42.3 44.4 0.0 0.9 0.1 17.7 15.1 6.5 24.7 27.6 83.5 93.4 39.729 105.098 2.645.~' 35.2 40.4 63.6 73.2 40.174 109.011 2.713~' 31.3 34.9 92.0 102.7 39.422 105.956 2.688 10.9 11.3 54.3 56.4 34.643 91.665 2.646 12.9 13.4 54.6 57.0 34.640 92.565 2.672 17.7 18.4 53.6 55.6 35.238 94.319 2.677 6.4 16.7 17.4 53.2 55.4 34.662 92.582 2.671 1.5 21.9 22,6 53.0 54.7 35.614 95.719 2.688 0.8 25.6 26.6 57.2 59.4 35.440 95.092 2.683 0.4 22.5 23.4 52.0 54.3 34.064 91.388 2.683 0.2 24.6 25.6 55.2 57.5 35.021 94.043 2.685 0.2 28.9 30.1 62.9 65.4 34.962 93.800 2.683 0.2 24.8 26.3 58.0 61.3 34.527 93.396 2.705 6.0 11.8 12.3 50.3 52.2 35.119 94.299 2.685 0.6 26.6 27.7 63.1 65.9 34.960 94.176 2.694 0.0 32.1 33.4 68.8 71.6 35.168 94.759 2.694 0.2 28.7 29.8 69.2 71.8 36.276 98.210 2.707 0.0 33.2 34.7 67.8 70.8 36.003 98.383 2.733 0.0 23.7 24,7 67.9 71.0 36.630 100.662 2.7481 20.0 21.8 60,7 66.1 37.440 108.705 2.903 0.1. 9.6 9.9 48.9 51.0 34.865 97.838 2.806 1.7 0.0 7.0 0.9 0.0 0.0 0.0 0.0 1.8 7.5 9.8 10.4 51.6 54.4 32.871 89.227 2.714 8.4 8.8 52.1 54.3 33.553 91.367 2.723 12.8 13.4 47.7 50.2 32.945 92.815 2.817 9.4 9.8 50.2 52.6 33.177 88.716 2.674 7.7 8.1 53.9 56,7 33,450 88.317 2.640 11.6 12.2 58.6 61,6 32.097 89.089 2.776 8.6 9.0 55.5 57.7 31.299 83.116 2.656 12.8 13.2 52.8 54.7 32.520 90.136 2.772 10.7 11.3 52.9 55.4 33.961 90.819 2.674 11.4 11.9 53.7 56,3 33.422 88.373 2.644 Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Horizontal Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Water Filtrate Oil Total Sample millidarcys Porosity, Volume, Saturation, Saturation, Saturation, Saturation, Grain Dry Grain Sample Depth, Klinkenber~l I to Air percent cc percent PV percent PV percent PV percent PV Volume, Weight, Density, Number feet 800psi I 3500psiI 800psi I 3500psi 800 psi13500 psi. S00psi13500psi 800 psi13500 psi 3500psi 800 psi13500 psi 800 psi13500 ps, cc ~rams ~m/cc 32A 10636.10 588. 552. 33A 10637.30 535. 483. 34A 10638.10 190. · 176. 35A 10639.10 552. 515. 36A 10640.60 898. 837. 37A 10641.40 153. 144. 38A 10642.10 46.3 44.3 39A 10643.30 300. 287. 40A 10644.15 0,485 0.011 41A 10645.10 42.4 40.3 42A 10646.30 296. 281. 43A 10647.10 346. 324. 44A 10648.10 3.63 3.31 45A 10649.30 104. 99.0 46A 10650.10 194. 185, 47A 10651.10 6.34 5.71 48A 10651.95 355. 323. 49A 10653.10 117. 111. 50A 10654.10 307. 289. 51A 10655.30 362. 337. 52A 10656.10 296. 278. 53A 10657.40 0.0030 0.0003 54A 10658.30 48.5 46.0 55A 10659.30 95.7 89.4 56A 10660.00 67.7 61.6 57A 10662.10 52.8 47.9 58A 10663.10 50.8 47.0 59A 10664.10 190. 179. 60A 10665.20 112. 102. 61A 10666.10 32.7 31.4 62A 10667.10 319. 294. 594. 545. 198. 560. 902. 160. 50.2 308. 0.530 46.0 304. 354. 4.64 110. 202. 7.71 373. 125. 316. 371. 305. 557. 493. 184. 525. 838. 151. 48.1 295. 26.8 25.9 11.509 10.986 39.7 41.6 26.7 25.7 11.527 10.940 55.5 58.5 23.8 23.0 10.219 9.764 50.7 53.1 26.7 25.9 11.549 11.103 52.7 54.8 28.0 26.9 12.012 11.374 45.1 47.6 22.2 21.2 9.453 8.954 41.9 44.3 19.5 18.8 8.453 8.094 39.7 41.5 23.1 22.4 10.009 9.601 39,7 41.4 0.027 4.9 4.2 2.152 1.802 73.9 88.2 43.8 18.1 17.5 7.868 7.556 43.2 45.0 288. 22.9 22.1 10.024 9.604 33.5 35.0 332. 24.2 23.4 10.442 10.005 41.2 43.0 4.22 17.4 16.8 7.538 7.198 46.4 48.6 105. 21.9 21.3 9.546 9.192 43.5 45.2 193. 22,7 22.2 9.830 9.571 43.3 44.5 6.96 17.3 16.6 7,440 7.064 49.4 52.1 340. 25.1 24.2 10.673 10.168 52.5 55.1 118. 22.5 22.0 9.657 9.349 49.1 50.7 298. 25.4 24.6 10.885 10,406 36.9 38.6 347. 25.0 24.4 10.822 10.470 45.5 47.1 287; 25.1 24.3 10.655 10,205 42.7 44.6 0.0066 0.0009 4.4 3.3 1.946 1.413 61.3 84.4 52.7 102. 73.4 58.0 55.3 197. 119. 35.6 328. 50.0 21.1 20.5 9.257 '8.886 45.8 47.7 95.4 24.0 23.2 10.151 9.752 50.1 52.1 66.9 23.6 22.7 10.031 9.549 51.8 54.4 52.8 23.2 22.4 9.928 9.459 54.4 57.1 51.3 21.6 21.0' 9.199 8.836 46.5 48.5 186. 23.8 23.2 10.197 9.887 46.2 47.7 109. 25.2 24.2 10.610 10.075 44.7 47.1 34.1 18.5 18.3 7.962 7.850 50.7 51.5 303. 26.5 25.6 11.074 10.573 43.3 45.4 1.0 11.8 12.3 51.4 53.9 31.510 83.131 2.638/ 1.6 8.4 8.8 63.9 67.3 31.627 83.500 2.640 1.4 2.6 2.7 53.3 55.8 32.725 86.549 2.645 1.2 7.5 7.8 60.2 62.6 31.728 83,712 2.638 1.2 11.8 12.4 56.9 60.1 30.913 81.468 2.635 2.0 11.0 11.6 53.0 55.9 33.202 87.653 2.640 2.7 11.8 12.4 51.6 53.9 34.900 93.256 2.672 0.0 16.3 17.0 56.0 58.4 33.301 88.884 2.669 0.0 17.0 20.3 90.9 108.5 41.536 112.999 2.720 3.1 10.1 10.5 53.3 55.5 35.606 95.922 2.694 0.0 12.0 12,6 45.6 47.5 33.800 92.921 2.749 1.1 17.3 18.1 58.5 61.1 32.668 86.174 2.638 0.0 11.4 11.9 57.7 60.5 35.764 96,119 2.688 0.0 6.9 7.2 50.4 52.4 34.012 91.573 2.692 0.0 8.5 8.7 51.8 53.2 33.519 91.190 2.721 1.8 13.7 14.4 63.1 66.5 35.552 95.130 2.676 1.8 11.2 11.7 63.7 66.8 31.920 85.620 2.682 4.4 13.4 13.9 62.5 64,6 33.224 90.975 2.738 0.0 13.6 14.2 50.5 52.8 31.952 84.949 2.659II', 0.0 14.0 14.4 59.5 61.5 32.416 86.646 2.673 0.0 13.9 14.5 56.6 59.1 31.805 84.659 2.662 0.0 21.1 29.1 82.4 113.5 41.785 120.000 2.872 1.1 13.0 13.5 58.8 61.2 34.560 94.208 2.726 1.3 7.6 8.0 57.7 60.1 32.198 87.399 2.714 1.9 12.1 12.7 63.9 67.1 32.502 87.467 2.691 53.5 6.8 7.1 61.2 64.3 32.856 89.752 2.732 7.3 10.9 11.3 57.4 59.8 33.296 92.118 2.767 1.6 9.1 9.4 55.3 57.1 32.683 88.984 2.723 1.6 10.1 10.6 54.8 57.7 31.539 86.406 2.740 11.8 9.3 9.4 60.0 60.9 35.081 103.481 2.950 1.6 9.7 10.1 53.0 55.5 30.658 82.610 2.695 Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Horizontal Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Water Filtrate Oil Total Sample millidarcys Porosity, Volume, Saturation, Saturation, Saturation, Saturation, Grain Dry Grain Sample Depth, Klinkenber~! I to Air percent cc percent PV percent PV percent PV percent PV Volume, Weight, Density, Number feet 800psi I 3500psiI 800psi I 3500psi 800 psi13500 psi! 800 psi13500 psi 800 psi13500 psi 3500psi 800 psi13500 psi 800psi13500ps~ cc ~lrams ~lm/cc 63A 10668.20 188. 174. 197. 64A 10669.10 153. 141. 161. 65A 10670.50 132.. 124. 141. 66A 10671.55 6.52 5.98 7.87 67A 10672.40 51.0 48.0 55.8 68A 10673.10 34.8 32.5 38.6 69A 10674.30 116. 109. 123. 70A 10675.10 78.1 72.8 83.9 71A 10676.10 52.5 45.1 57.4 72A 10677.30 209. 185. 219. 73A 10678.10 448. 408. 456. 74A 10679.10 477. 442. 483. 75A 10680.30 241. 219. 250. 76A 10681.10 120. 112. 127. 77A 10682.10 98.9 89.1 107. 78A 10683.30 199. 179. 210. 79A 10684.10 581. 533. 586. 80A 10685.10 482. 447. 488. 81A 10686.30 474. 440. 480. 82A 10687.10 424. 388. 432. 83A 10688.00 392. 367. 399. 84A 10689.30 10.0 9.59 11.4 85A 10690.10 56.1 54.0 60.2 86A 10691.30 0.0029 0.0068 87A 10692.10 79.8 76.1 83.8 88A 10693.90 9.70 9.23 10.9 89A 10695.10 0.356 0.070 0.557 90A 10696.20 49.2 46.4 54.0 91A 10697.10 17.6 16.2 20.2 92A 10698.25 75.1 71.2 80.6 93A 10699.10 33.1 31.5 36.6 183. 26.1 25.4 11.157 10.750 48.9 50.8 148. 26.0 25.1 11,031 10.565 52.3 54.6 132. 23.7 23.0 10.230 9.835 43.7 45.5 7.23 17.5 16.7 7.477 7.058 47.0 49.8 52.6 21.9 21.2 9.338 8.959 44.9 46.8 36.2 21.7 20.9 9.329 8,863 44.5 46.8 116. 24.1 23.3 10.404 9.935 42.6 44.7 78.5 23.7 22.8 10.381 9.834 42.6 45.0 49.6 21.8 20.9 9,242 8.777 48.2 50.8 194, 25.2 24.2 10.419 9.910 40.6 42.7 417. 28.2 27.0 11.659 10,972 36.7 39.0 448. 27,5 26.7 11.703 11.255 41.7 43.4 228. 27.0 26.0 11.217 10.668 45,3 47.6 119, 24.0 23.3 10.310 9.948 48.2 50.0 96.4 24.5 23.5 10.474 9.924 52.1 55.0 190. 24.4 23.6 10.237 9.805 50.3 52.5 540. 28.2 27.3 11.849 tl.354 42.5 44.3 454. 27.2 26.3 11.685 11,152 43.3 45.4 446. 26.9 26.2 11.514 11.084 45.0 46.7 397. 27.4 26.5 11.646 11.134 44,9 47.0 375. 24.2 23.5 10:324 9.907 44.2 46.1 10.9 14.0 13.6 6.103 5.900 39.3 40.6 58.0 18.3 17.7 7.998 7.699 36.9 38.3 4.0 - 1.736 98.0 79.9 18.8 18.1 8.211 7.863 32.7 34.1 10.3 14.2 13.7 6.185 5.910 45.6 47.7 0.128 10.0 8,9 4.210 3.737 58.8 66.3 51.1 22.1 21.4 9.439 9.071 41.9 43.6 18.7 19.7 19.1 8.386' 8.057 44.9 46.7 76.5 22.5 21.7 9.631 9.212 40.2 42.1 34.8 19.5 19.0 8,377 8.122 44.7 46.1 0.0 1.0 1.4 0.0 0.0 1.1 0.0 1.2 8.5 8.8 57.4 59.6 31.552 84.049 2.66z~~ 5.3 5.5 57.6 60.2 31.473 84.292 2.678"-'~ 9.6 10.0 53.3 55.4 32.975 89.091 2.702 7.2 7.6 54.2 57.4 35.311 96.114 2.722 6.0 6.3 50.9 53.1 33.205 89.357 2.691 7.4 7.8 51.9 54.6 33.603 90.865 2.704 8.9 9.4 51.6 54.0 32.772 88.207 2.692 8.5 8.9 51.1 53.9 33.346 88.960 2.668 1.5 10.9 11.4 59.1 62.2 33.200 94.175 2.837 6.5 12.7 13.4 53.4 56.1 30.961 83.873 2.709 1.2 16.0 17.0 52,7 56.0 29.661 79.295 2.673 1.5 12.1 12.6 53.8 55.9 30.910 84.463 2.733 0.9 7.8 8.2 53.0 55.8 30.306 80.617 2.660 0.0 10.4 10.8 58.6 60.7 32.672 87.770 2.686 1.0 9.1 9,6 61.2 64.6 32.240 85.776 2.661 1.2 9.1 9.4 59.4 62.0 31.726 87.405 2.755 1,1 9.3 9.7 51.7 54.0 30.183 80.059 2.652 0.8 9.2 9.7 52,5 55.0 31.273 83.633 2.674 0.6 9.1 9.4 54.0 56.1 31.257 83.978 2.687i 0.9 10.5 11.0 55.5 58.0 30.885 82,067 2.657 0.0 33.5 34.9 77.7 81,0 32.274 87.905 2.724 3.0 '12.8 13.2 52.1 53.9 37.396 103.828 2.776 2.5 13.2 13.7 50.1 52.1 35.716 96.597 2.705 0.0 5.8 - 103.8 - 41.366 111.917 2.706 0.0 13.9 14.6 46.6 48.7 35.471 95.819 2.701 0.0 10.2 10.7 55.8 58.4 37.249 106.573 2.861 5.1 18.7 21.1 77.6 87.4 38.104 104.183 2.734 0.0 9.5 9.9 51.5 53.6 33.322 89.204 2.677 0,0 10.8 11.3 55.7 58.0 34.097 91.847 2.694 0.6 1013 10.8 50.6 52.9 33.177 88.925 2.680 3.4 10.9 11.3 55.6 57.4 34.678 95.972 2.768 Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Horizontal Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Water Filtrate Oil Total Sample millidarcys Porosity, Volume, Saturation, Saturation, Saturation, Saturation, Grain Dry Grain Sample Depth, Klinkenber~ I to Air percent cc percent PV percent PV percent PV percent PV Volume, Weight, Density, Number feet 800 psi I 3500 psiI 800 psi I 3500 psi 800 psi13500 psi. 800 psi13500 psi 800 psi13500 psi 3500 psi 800 psi13500 psi 800 psi13500 ps~ cc grams ~lm/cc 94A 10700.10 5.82 5.26 7.14 95A 10701.10 31.5 29.5 35.2 96A 10702.20 6.58 5.99 7.95 97A 10703.10 8.18 7.30 9.80 98A 10704.40 3.71 2.50 4.70 99^ 10705.15 45.0 41.6 48.5 100A 10706.55 347. 323. 353. 101A 10707.10 285. 265. 292. 102A 10708.30 169. 158. 176. 103A 10709.10 113. 107. 119. 104A 10710.50 41.6 38.1 45.6 105A 10711.65 130. 122, 136. 106A 10712.10 175. 165. 183. 107A 10713.10 223. 207. 231. 108A 10714.10 40.5 38.6 43.2 109^ 10715.10 345. 321. 354. 110A 10716.10 65.5 59.9 71,1 111A 10717.40 14.1 12.5 16.2 112A 10718.10 249. 230. 258. 113A 10719.10 219. 205. 227. 114A 10720.30 154. 144. 162. 115A 10722.50 165. 153. 172. 116A 10724.10 81.7 76.3 87.5 117A 10725.10 37,5 35.4 40.7 118A 10726.10 21.3 19,7 24.3 119A 10727.10 21.9 20.3 24.6 120A 10728.20 95.2 89.0 102. 121A 10729.10 35.2 32.1 38.7 122A 10730.10 65.1 57.0 70.4 123A 10731.15 8.10 7.49 9.57 124A 10732.65 9.67 9.10 10.9 6.44 17.3 16.4 7.416 6.966 44.7 47.6 32.9 20.2 19.6 8.676 8.353 44.1 45.8 7.25 17.2 16.4 7.492 7.081 44.3 46.9 8.80 17.7 17.0 7,450 7,080 50.9 53.6 3.20 15.9 14.9 6.766 6.275 57.7 62.2 44.8 19.2 18.4 8.337 7,892 43.9 46.3 330. 24.0 23.3 10.305 9.918 47.3 49.2 272. 24.6 23.9 10.588 10.191 45.6 47.4 165. 23.7 23.1 10.143 9.776 44.5 46.2 4.0 11.0 11.7 55.7 59.3 35.408 94.441 2.66;~ 0.0 10.1 10.5 54.2 56.3 34.323 91.858 2.676 0.0 13.2 14.0 57.5 60.9 36.040 96.182 2.669 0.0 10.7 11.3 61.6 64.9 34.662 91.849 2.650 1.9 10.6 11.4 68.3 73.6 35.777 97.568 2.727 0.0 10.9 11.5 54.7 57.8 35.059 94.168 2.686 1.5 8.9 9.3 56.2 58.4 32.613 88.134 2.702 1.2 10.9 11.3 56.5 58.7 32.514 87.945 2.705 1.0 12.6 13.1 57.1 59.3 32.571 87.038 2.672 113. 20.7 20.1 9.033 8.714 48.4 50.2 13.7 12.0 12.5 60.4 62,7 34.569 97.515 2.821 41.9 21.2 20.6 9.011 8.650 50.5 52.6 12.7 11.9 12.4 62.4 65.0 33.420 89.868 2.689 129. 22.8 22.1 9.625 9.271 43.9 45.6 14.6 9.9 10,2 53.7 55.8 32.603 87.345 2,679 173. 22.6 22.0 9.702 9.378 43.1 44.6 216. 23.5 23.0 10.076 9.752 43.9 45.4 41.2 17.5 17.0 7.612 7.332 52.7 54.7 330. 25.3 24.5 10.824 10.381 56.4 58.8 65.2 21.6 20.8 9.260 8.801 52.7 55.4 14.4 17.8 17.0 7.656 7.240 54.9 58.1 239. 25,0 24,3 10.636 10.270 44.2 45.8 1.2 12.4 12.9 55.5 57.4 33.275 90,051 2.706 1.9 12.2 12.6 56.1 58.0 32.730 88.882 2.716 3.0 8.1 8.4 60.7 63.1 35.873 104.058 2.901 1.2 12.1 12.6 68.4 71.3 31.960 84.947 2.658 1.3 11.0 11.5 63.6 67,0 33.559 89.781 2.675 4.9 12.0 12.7 66.9 70.8 35.367 93.784 2.65Z 1.5 14.3 14.8 58.5 60.6 31.985 85.452 2.67'~. 214. 152. 161. 81.9 22.5 21.8 9.584 9.236 46.0 47.8 38.5 18,9 18.2 8,124 7.766 44.2 46.2 22.4 19.4 18.7 8.375 8.030 40.8 42.5 22.9 19.3 18.5 8.282 7.877 44.8 47.1 95.0 22.5 21.8 9.757 9.363 43.2 45.0 35.4 19.3 18.5 8.212 7.785 46.7 49.2 61.7 20.1 19.3 8.481 8.081 49.5 51.9 8.86 16.6 16.0 7.102 6.812 41.5 43.2 10.3 14.2 13.7 6.092 5.824 38.6 40.4 24.3 23.6 10.410 9.985 48.7 50.7 10.0 18.0 18.8 66.7 69.5 32.360 87.304 2.698 24.5 23.9 10.557 10.195 47.7 49,4 3.8 14.9 15,4 62.5 64.8 32.517 88.526 2.722 23.2 22.4 9.639 9.249 54.7 57.0 44.2 11.2 11.6 65.9 68.7 31.993 86.637 2.708 3.8 11.8 12.2 57.8 60.0 33.106 89.205 2.695 1.5 12.4 13.0 56.6 59.2 34.965 99.862 2.856 1.2 16.0 16.7 56.7 59.2 34,830 92.973 2.669 1.3 8,9 9.4 53.7 56,4 34.598 92.447 2.672 0.0 10.8 11.3 54.0 56.2 33.611 90.627 2.696 2.2 10.8 11.3 57.4 60.6 34.308 95.576 2.786 1.5 15.0 15.8 64.5 67.7 33.750 91.978 2.725 0.0 23.9 24.9 65.4 68.1 35.671 94.793 2.657 2.8 8.9 9,4 47.6 49.8 36.771 99.360 2.702 Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Horizontal Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Water Filtrate Oil Total Sample millidarc¥s Porosity, Volume, Saturation, Saturation, Saturation, Saturation, Grain Dry Grain Sample Depth, Klinkenberg I to Air percent cc percent PV percent PV percent PV percent PV Volume, Weight, Density, .Number feet 800 psi I 3500 psiI 800 psi I 3500 psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 psi 3500 psi 800 psi13500 psi 800 psi13500 ps~ cc grams gm/cc 125A 10733.10 13.9 12.9 15.4 126A 10734.65 0.0024 * 0.011 127A 10735.10 0.354 0.334 0.423 128A 10736.25 0.020 0.0010 0.037 129A 10736.90 15.0 14.3 16.9 130A 10738.25 0.320 0.0039 0.334 131A 10739.10 69.8 66.4 73.5 132A 10740.30 0.015 0.0067 0.030 133A 10741.30 0.423 0.0061 0.436 134A 10742.10 0.630 0.577 0.748 135A 10743.30 69.7 64.8 74.4 136A 10744.10 70.4 * 73.2 137A 10745.10 128. * 131. 138A 10746.40 133. 124. 139. 139A 10747.10 138. 129. 145. 140A 10748.45 14.9 13.3 17.4 141A 10749.40 267. 251. 275. 142A 10750.10 219. 201. 226. 143A 10751.60 46.3 42.3 50.3 144A 10752.15 74.0 69.9 79.1 145A 10753.10 208. 196. 215. 146A 10754.20 77.3 70.9 82.9 147A 10755.70 87.5 78.8 93.3 148A 10756.75 77.0 68.3 82.5 149A 10757.40 110. 103. 117. 150A 10758.40 203. 186. 211. 151A 10759.20 209. 195. 217. 152A 10760.10 188. 176. 195. 153A 10761.10 56.9 53.5 61.1 154A 10762.10 5.96 5.53 7.01 155A 10763.10 33.0 31.4 35.6 130. 136. 15.5 258. 208. 46.0 74.9 204. 76.3 84.4 73.6 109. 194. 202. 183. 57.7 14.3 13.5 13.0 5.804 5.512 31.8 33.5 1.9 3.6 1.503 84.9 0.395 6.0 5.6 2.649 2.449 27.8 30.0 0.0 0.0029 5.1 3.9 2.114 1.590 55.4 73.7 0.0 16.2 16.1 15.6 7.165 6.911 37.6 39.0 0.0 0.010 3.8 2.9 1.636 1.221 66.3 88.8 0.0 70.0 17.9 17.4 7.605 7.331 32.6 33.8 0.0 0.018 6.7 6.5 2.982 2.875 55.0 57,1 0.0 0.016 4.0 2.4 1.735 1.014 30.8 52.8 0.0 0.687 9.0 8.6 4.054 3.848 55.4 58.4 3.3 69.2 20.9 20.1 8,920 8.498 47.4 49.7 2.2 20.8 8,947 42.6 24.5 10.459 44.0 21.7 21.1 9,393 9.078 43.4 44.9 0.0 22,9 22.3 9,996 9.679 41.0 42.4 1.4 20.1 19.1 8.516 8.002 23.9 25,5 0.8 23.8 23.1 10.521 10.127 43.8 45.5 1,6 23.3 22.6 10,131 9.727 49.2 51.2 1.6 20.0 19.2 8.589 8,116 47.5 50.3 3.5 20.9 20.2 8.987 8.610 30.3 31.7 1.1 22.2 21.7 9.785 9.476 40.1 41.5 0.0 22.4 21.6 9,289 8.898 47.9 50.0 1.0 22.8 22.0 9.609 9.203 44.1 46.0 1.0 23.2 22.5 9.797 9.394 48.3 50.3 1.9 23.1 22.5 9,767 9,421 45.8 47.5 0.0 26.1 25.1 11.135 10,608 51.8 54.4 1,1 24.3 23.4 10.277 9.774 47.7 50,2 0.0 23.2 22.6 9.994 9.681 51.2 52.8 0.0 20.9 20.1 9.052 8.613 45,8 48.1 0.0 6.50 15.1 14.4 6.586 6.219 51.4 54.4 2.0 33.9 16.7 15.9 7.240 6.850 44.0 46.5 1.6 13.3 14.0 45.1 47.5 37.049 99.865 2.696,,' 6.4 91.2 40.717 116.316 2.857~'~''~ 25.4 27.4 53.1 57.5 41.188 117.943 2.864 20.7 27.5 76.1 101.2 38.995 103.547 2.655 11.2 11.6 48.8 50.6 37.298 98.513 2.641 36.1 48,3 102.3 137.1 41.619 114.008 2.739 9.4 9.8 42.0 43.6 34.871 93.838 2.691 21.6 22,5 76.7 79.5 41.365 116.540 2.817 42.9 73.4 73.7 126.2 41.360 109.947 2.658 1.0 1,1 56.4 59.5 40.809 124.364 3.047 10.6 11.1 57.9 60.8 33.730 94.946 2.815 18.6 61.3 34.093 92.536 2.714 13.7 57.7 32.302 88.128 2.728 13.0 13.4 56.3 58.3 33.988 97.536 2.870 19.9 20.6 61.0 63.0 33.728 95.208 2.823 40.6 43.2 64,5 68.7 33.919 92.165 2.717 11.9 12,4 55.7 57.8 33.650 92.917 2.761 9.9 10.3 59.1 61.5 33.373 93.491 2.801 13.0 13.7 60.5 64.0 34.251 94.700 2.765t' 22.4 23.3 52.7 55.0 33.998 92.417 2.718' 12.6 13.0 52.7 54.4 34.195 93.228 2.726 10.6 11,0 58.4 61.0 32.243 87.522 2.714 12.1 12.6 56.1 58.6 32.541 87.904 2.701 11.8 12.3 60.1 62.7 32.436 86,562 2.669 12.4 12.9 58.3 60.4 32.520 90.136 2.772 10.7 11.2 62.5 65.6 31.580 87.060 2.757 13.9 14.6 61.6 64.8 32.051 89.182 2.783 13.1 13.5 64.3 66,4 33.138 90.568 2,733 14.7 15.5 60.5 63.6 34.278 94.277 2.750 15.5 16.4 66.8 70,8 37.019 102.081 2.758 16.8 17.8 60.8 64,3 36.211 104.078 2.874 Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Horizontal Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Water Filtrate Oil Total Sample millidarcys Porosity, Volume, Saturation, Saturation, Saturation, Saturation, Grain Dry Grain Sample Depth, Klinkenber~l I to Air percent cc percent PV percent PV percent PV percent PV Volume,: Weight, Density, _Number feet 800 psi I 3500 psiI 800 psi I 3500 psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 psi 3500 psi 800 psi13500 psi 800 psi13500 ps~ cc grams gm/cc 156A 10764.10 453. 426. 157A 10765.40 601. 552. 158A 10766.10 468. · 429. 159A 10767.10 191. 174. 160A 10768.10 258. 240. 161A 10769.10 352. 334. 162A 10770.10 379. 356. 163A 10771.40 327. 302. 164A 10772.10 238. 218. 165A 10773.10 219. 207. 166A 10774.20 149. 141. 167A 10775.10 270. 255. 168A 10776.10 273. 257. 169A 10777.20 234. 217. 170A 10778.10 308. 286. 171A 10779.10 1320. 520. 172A 10780.40 442. 406. 173A 10781.70 684. 639. 174A 10782.10 858. 790. 175A 10786.20 279. 263. 176A 10787.10 748. 646. 177A 10788.10 465. 424. 178A 10789.50 456. 423. 179A 10790.20 367. 341. 180A 10791.10 802. 749. 181A 10792.10 743. 654. 182A 10793.30 595. 527. 183A 10794.10 355. 327. 184A 10795.10 721. 617. 185A 10796.30 1220. 1070. 186A 10797.10 875. 788. 456. 430. 604. 555. 474. 436. 198. 181. 266. 248. 358. 340. 385. 363. 335. 310. 247. 227. 228. 215. 156. 148. 279. 264. 282. 267. 243. 226. 319. 297. 1380. 558. 450. 415. 693. 650. 862. 797. 289. 272. 753. 655. 477. 437. 472. 438. 376. 350. 808. 756. 749. 662. 602. 536. 366. 338. 727. 626. 1240. 1100. 878. 796. 22,1 21.6 9.735 9,428 41.9 43,3 25.0 24.1 11,000 10.473 49.1 51.6 25,0 24,3 10,511 10.112 47.7 49,5 22,8 22,0 9.916 9.505 51,2 53,5 23,2 22.6 10.102 9.757 53,3 55,2 24,3 23,5 10,185 9,771 51,1 53,3 24,4 23,5 10,388 9.930 47,8 50,0 24,8 24.0 10,788 10,339 50.9 53.1 26.1 25.4 11,331 10.869 55,9 58,3 24,9 24.2 10,481 10,116 45,9 47,5 23,9 23.2 10,497 10,118 44.4 46,1 25,4 24.7 10,791 10,414 44.5 46,1 25,2 24,5 11,076 10.709 47,1 48.7 25,4 24,6 10,924 10,469 49.6 51,7 26.3 25.3 10,983 10.455 49,6 52.1 25,7 24,8 11,200 10,638 43.6 46,0 27,3 26.3 11,375 10,818 46,0 48,4 28,1 27,4 12,233 11,805 40.3 41,7 28,3 27.3 12,325 11,706 4.6 4.9 25.4 24,6 11,095 10,619 41,3 43,2 28,1 27,1 12,167 11,545 44,6 47,0 28,0 27,2 11,988 11,516 46,2 48,1 25.3 24,6 11,046 10,677 40,5 41,9 25,4 24,8 11,110 10,739 43,4 44.9 28,1 27.3 12,205 11,737 39.0 40,6 28,1 27,2 11,964 11,426 44,6 46,7 27,7 26,7' 11,753 11,144 51,3 54,1 26,0 25,1 11,073 10,564 54.2 56.8 28,2 27,1 11,829 11,192 52,5 55.5 29,2 28,1 12,302 11,656 50.1 52,9 27,5 26,7 11,636 11,156 52,8 55,0 0,0 19,7 20,4 61,7 63,7 34,298 95.538 2,786~iI 1.0 18.5 19.4 67,6 71,0 33,031 91.082 2.757' 1,4 19.4 20.1 67,0 69,7 31,584 86.258 2,731 1.1 19.6 20.4 70,8 73,9 33,622 90,565 2.694 2.0 18.2 18.9 71,5' 74.0 33.432 90.229 2.699 1,9 17,5 18,2 68,6 71,5 31,782 85,479 2,690 1,3 18,7 19,6 66.6 69,6 32,244 89,645 2.780 0,0 19,4 20,3 70,3 73,4 32,788 89,171 2,720 1.2 17,8 18,5 73,7 76,8 32,001 85,023 2,657 1.2 21,9 22,7 67,8 70,2 31,602 84,776 2,683 1.2 20.5 21,3 64.9 67.4 33.513 90,153 2.690 1,0 20,5 21,2 65,0 67,4 31,746 86,228 2,716 1,4 20,5 21,2 67,6 69,9 32.932 88,927 2,700 0,9 20,9 21,8 70,5 73,5 32,082 85,846 2,676 1,4 16.5 17,3 66,1 69.4 30,791 81,660 2,652 1,7 24,9 26,2 68,5 72,1 32,331 92,451 2,860 1,7 21,1 22,1 67,1 70.6 30,326 87,281 2,878 1,0 26,6 27,5 66,8 69,3 31,248 85,354 2,732. 0,0 66,7 70,3 71,4 75,1 31,187 87,212 2,796~ 40,6 23,7 24,8 65,1 68,0 32,506 86,330 2,656 41,3 20,0 21,0 64,5 68.0 31,061 85,733 2,760 43.0 21,5 22,4 67,7 70,5 30,758 82,509 2,683 15,7 26,5 27,4 67,0 69,3 32,671 91,811 2,810 36,3 25,1 25,9 68,5 70,8 32,563 89,495 2,748 32,3 27,7 28,8 66,7 69.4 31,230 82,545 2,643 1,5 22,8 23,9 67,4 70,5 30,618 84,400 2,757 2,5 15,4 16,2 66,7 70.3 30,650 83,711 2,731 1,8 14.6 15.3 68.8 72.1 31,512 85.288 2.707 3,1 18,3 19,3 70,8 74,9 30,140 82,225 2,728 10.5 21,4 22,6 71,5 75,5 29,819 80.979 2,716 3.5 21,0 21,9 73,8 76,9 30,639 85,175 2,780 Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Horizontal Dean Stark Samples British Petroleum File: DAL-97369 13-08A Well Permeability, Pore Water Filtrate Oil Total Sample millidarcys Porosity, Volume, Saturation, Saturation, Saturation, Saturation, Grain Dry Grain Sample Depth, Klinkenber~l I to Air percent cc percent PV percent PV percent PV percent PV Volume, Weight, Density, Number feet 800 psi I 3500 psiI 800 psi I 3500 psi 800 psi13500 psiI 800 psi13500 psi 800 psi13500 psi 3500 psi 800 psi13500 psi 800 psi13500 ps, cc grams gm/cc 187A 10798.10 686. 593. 700. 606. 28.7 27.6 12,066 11.404 54.3 57.5 3.5 18.5 19.6 72.8 77.1 29.928 81.238 2.7141/ 188A 10799.35 1100. 941. 1130. 962. 29.5 28.2 12.483 11.709 50.1 53.4 1.2 19.8 21.1 69.9 74.5 29.821 81.222 2.724 189A 10800.10 986.. 876. 990. 883. 28.0 27.1 11.984 11.477 57.5 60.0 1.5 14,7 15.4 72.2 75.4 30.834 84.424 2.738 190A 10801.10 760. 661. 767. 669. 27.7 26.7 11.723 11.153 54.6 57.4 1.7 14.9 15.7 69.5 73.0 30.612 83.728 2.735 191A 10802.20 323. 302. 334. 312. 25.9 25.3 11,059 10.686 46.1 47.7 1.4 21.5 22.3 67.6 70.0 31.633 85.099 2.690 192A 10803.10 490. 458. 500. 468, 26.5 25.9 11,354 10.986 44,5 46.0 1.2 20.9 21.6 65.3 67.5 31.478 84.036 2.670 193A 10804.60 0.717 0.163 1.01 0.252 12.8 11.8 5,438 4.977 72.1 78.8 2.5 12.8 13.9 84.9 92.7 37.129 99.171 2.671 194A 10805.70 4.16 1,79 5.09 2.24 15.6 14.5 6.618 6.088 69.4 75.4 1,4 11.3 12.3 80.6 87.7 35.781 94.908 2.652 195A 10806.10 501. 522. * 23.0 0.0 10.064 0.000 32.1 32.9 0.0 65.0 0.0 33.726 89.382 2.650 196A 10807.10 2500, 2320. 2630. 2400. 28.8 27.7 12.213 11.564 46.4 49.0 1.8 19.8 20,9 66.2 69.9 30.244 80,043 2.647 203A 10815.25 2090. 2140. * 30.0 0.0 13,123 0.000 37.1 31,3 0,0 68.4 0.0 30.667 82.817 2.701 204A 10816.70 1500. 1320. 1530, 1340. 28.0 27.1 11,996 11.461 42.0 43.9 6.7 24.9 26,1 66.9 70.0 30,828 82.540 2.677 205A 10817.70 793, 747. 800. 751, 22,9 22.3 10.035 9,676 45.3 46.9 9,5 23.6 24.5 68.9 71.4 33.803 95.468 2.824 209A 10821.70 609. 487, 652. 502. 22.3 21.3 9.470 8.972 39.9 42.2 7.6 39,8 42,0 79.8 84.2 33.051 91,028 2,754 * Sample Unsuitable for CMS - PV = HgBV - GV, PDPK Permeability +++ Sample failed in CMS, not recoverable - PV - (L*A)BV - GV, PDPK Permeability Core Laboratories 10000 1000 100 0.01 0.001 0.0001 KLINKENBERG PERMEABILITY VERSUS POROSITY 13o06A WELL 0 6 12 18 24 30 Porosity, percent ® 800 psi e 3500 psi Core Laboratories 10000 lOOO lOO O.Ol o.ool o.oool PERMEABILITY TO AIR VERSUS POROSITY 13-06A WELL · ,it, 0 6 12 18 24 30 36 Porosity, percent · 800 psi ~ 3500 psi Core Laboratories lO0 80 20 WATER SATURATION VERSUS POROSITY 13-06A WELL 0 6 12 18 24 30 36 Porosity, percent · 800 psi ~ 3500 psi Core Laboratories 100 80 60 0 40 20 OIL SATURATION VERSUS POROSITY 13-06A WELL · dB, ee . _-e d · ~ e~ · ~e 0 6 12 18 24 30 36 Porosity, percent · 800 psi m 3500 psi Core Laboratories 100 80 60 40 20 OIL SATURATION VERSUS DEPTH 13o06AWELL 0 10500 10600 10700 10800 10900 De~h, feet 800 psi = 3500 psi Core Laboratories ARCO Alaska, Inc. File: DAL-97369 Section 4 VERTICAL PLUG DATA Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Vertical Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Uncorrected Filtrate Corrected Filtrate Oil Uncorrected Corrected Sample millidarcys Porosity, Volume, Water Saturation, Water Saturation, Saturation, Saturation, Total Saturation, Total Saturation, Grain Dry Grain Sample Depth. Klinkenberg [ to Air percent cc percent PV percent PV percent PV percent PV percent PV percent PV Volume. Weight. Density. Numbe~ feet 800psi t 3500psiI 800psi [ 3500psi 1800psi[3500ps 800psi [3500psi 800psi[ 3500psi 800psi[ 3500psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 ps~ cc grams gm/cc 1V 10523.30 0.0031 0.0014 0,0093 0.0033 7.1 ¢7 3.071 1.999 35.909 55.161 35,6 54.7 0.3 0.5 16.3 25.0 52.2 80.2 51.9 79.7 40.221 107.230 2.666 2V 10524.30 0.045 0.029 0.095 0.064 11.3 10.6 4.934 4.589 36.279 39.003 32.7 35.2 3.6 3.8 29.7 32.0 66.0 71.0 62.4 67,1 38.646 111.037 2.873 3V 10525.30 0.010 0.0002 0.019 0.0005 11.2 8.4 4.842 3.491 83.594 115.943 82.0 113.8 1.6 2.2 19.3 26.8 102.9 142,7 101.3 140.5 38.260 113.927 2.978 4V 10526.30 9.83 8.75 11.2 10.0 18.6 18.1 8.120 7.824 41.271 42.836 27.1 28.1 14.2 14.7 16.4 17.1 57.7 59.9 43.5 45.2 35.422 99.747 2.816',i 5V 10527.30 2.75 2.38 3.61 3.11 18.0 17.4 7.727 7.403 39.417 41.139 32.9 34.3 6.5 6.8 16.2 17.0 55.7 58,1 49.1 51.3 35.103 94.328 2.687~,~ 6V 10528.30 17.4 16.4 20.1 18.9 21.0 20.3 9.104 8.724 34,937 36.457 29.8 31.1 5.2 5.4 19.2 20.1 54.2 56.5 49.0 51.1 34.192 92.029 2.692 7V 10529.30 12.2 11.4 14.0 13.1 19.0 18.3 8.234 7.893 36.089 37.648 33.3 34.7 2.8 2.9 16.0 16.7 52.1 54.4 49.3 51.5 35.123 94.143 2.680 8V 10530.30 6.67 6.18 7.88 7.30 18.0 17.5 7.873 7.613 33.974 35.133 33.3 34.4 0.7 0.7 23.7 24.5 57.7 59.6 57.0 58.9 35.893 96.857 2.698 9V 10531.20 14.1 13.2 16.2 15.2 19.4 18.9 8.421 8.116 28.839 29.921 28.5 29.5 0.4 0.4 25.4 26.4 54.2 56.3 53.9 55.9 34.923 93.392 2.674 10V 10532.30 8.96 8.34 10.5 9.8 19.0 18.4 8.160 7.830 31.075 32.384 31.0 32.3 0.1 0.1 23,5 24.5 54.6 56.9 54.5 56.8 34.736 93.489 2.691 11V 10533.20 11.8 11.0 13.9 12.9 19.9 19.3 8.586 8.224 31.415 32.796 31.3 32.7 0.1 0.1 24.8 25.9 56.2 58.7 56.1 58.6 34.473 92.683 2.689 12V 10534.20 13.6 12.7 15.8 14.7 20.3 19,6 8.922 8.550 31.970 33.358 31.9 33.3 0.0 0.0 31.7 33.1 63.7 66.5 63.7 66.4 35.123 94.158 2.681 13V 10535.30 4.86 4.49 5.93 5.46 18.7 18.1 8.060 7.732 36.199 37.733 35.9 37.4 0.3 0.4 22.2 23.2 58.4 60.9 58.1 60.6 34.984 93.754 2.680 14V 10536.20 3.56 3.22 4.44 4.00 18.1 17.5 7.934 7.628 39.922 41.526 37.6 39.2 2.3 2.4 12.6 13.1 52.5 54.6 50.2 52.2 36.009 97.018 2.694 15V 10537.30 3.19 2.94 . 4.05 3.72 18.6 17.8 8.183 7.733 34.153 36.144 33.7 35.7 0.4 0.5 24.0 25.4 58.1 61.5 57.7 61.1 35.731 97.010 2.715 16V 10538.20 4.73 4.35 5.83 5.36 18.8 18.1 8.075 7.684 36.410 38.262 36.5 38.3 0.0 0,0 31.7 33.4 68.2 71.6 68,2 71.7 34.793 93.525 2.688 17V 10539.20 2.44 2.30 3.09 2.87 17.0 16.5 7.474 7.204 40.302 41.810 40.3 41.8 0.0 0.0 30.1 31.2 70.4 73.0 70.4 73.0 36.541 98.781 2.703 18V 10540.30 2.86 2.67 3.67 3.40 17.0 16.5 7.344 7.082 32.938 34.157 32.8 34.0 0.2 0.2 30.9 32.1 63.9 66.2 63.7 66.1 35.777 98.659 2.758 19V 10541.20 5.04 4.79 6.05 5.75 17.3 16.6 7.643 7.278 43.237 45.408 43.2 45.4 0.0 0.0 23.6 24.8 66.9 70.2 66.9 70.2 36.460 99.857 2.739 20V 10624.00 10.4 6.61 12.0 7.69 18.6 17.7 10.224 9.590 33.739 35.969 22.0 23.5 11.7 12.5 14.8 15.8 48.5 51.8 36.8 39.2 44.675 126.601 2.834 21V 10625.00 71.2 67.1 77.3 73.1 21.2 20.7 12.270 11.885 36.743 37.935 10.3 10.7 47.1 48.6 45.503 123.407 2.712 22V 10626.00 15.8 14.5 18.6 17.0 21.3 20.4 7.817 7.422 36.588 38.534 9.8 10.3 46.4 48,8 28.947 79.790 2.756 23V 10627.00 10.7 9.12 13.6 11.5 20.8 20.2 11.863 11.452 40.774 42.238 9.1 9.4 49.9 51.6 45.152 124.762 2.763 25V 10629.00 29.3 27.3 34.9 32.6 22.2 21.5 12.572 12.114 38.790 40.254 38.8 40.3 0.0 0.0 10.3 10.7 49.1 50.9 49.1 50.9 44.155 116.821 2.646 26V 10630.50 75.0 69.6 81.7 75.9 24.3 23.5 13.656 13,058 44.082 46.101 8.8 9.2 52.9 55.3 42.550 114.387 2.688 10631.00 368. 348. 383. 363. 25.8 25.4 14.519 14.210 42.409 43.331 12.8 13.1 55.2 56.4 41.780 110.676 2,649 27V 28V 10632.00 100. 92.6 105. 97.2 22.7 21.9 12.911 12.334 46.700 48.885 10.7 11.2 57.4 60.1 44.022 125.874 2.859'~ 29V 10633.20 343. 320. 356. 332. 25.7 24.9 14.421 13.801 42.859 44.783 8.8 9.2 51,7 54.0 41.621 110.202 2.648 30V 10634.20 13.2 11.3 15.9 13.5 21.8 20.9 11.129 10.551 42.868 45.216 42.9 45.2 0.0 0.0 8.3 8.7 51.1 53.9 51.1 53.9 39.982 108.381 2.711 31V 10635.00 161. 149. 174. 162. 24.9 24.2 14.209 13.642 40.100 41.766 9.6 10.0 49.7 51.7 42.813 112.828 2.635 32V 10636.00 501. 465. 518. 483. 27.4 26.7 15.547 14.990 38.557 39.990 9.4 9.8 48.0 49.8 41.109 108.523 2.640 33V 10637.00 19.2 13.9 22.9 16.6 23,8 22.9 11.359 10.761 52.212 55.113 5.1 5.4 57.3 60.5 36.278 95.556 2.634 34V 10638.00 48.4 45.0 53.3 49.6 21.4 20.9 12.101 11.746 50.846 52.381 5.4 5.6 56.2 57.9 44.561 117.752 2.642 35V 10639.00 3.53 3.15 5.29 4,57 23.7 23.3 13.154 12.876 47.904 48.937 47.9 48.9 0.0 0.0 8.6 8.8 56.5 57.7 56.5 57.7 42,396 111.704 2.635 36V 10640.50 353. 324. 366. 336. 26.9 26.0 14.875 14.184 43.611 45.733 37V 10641.30 154. 147. 161. 154. 22.7 22.3 11.303 10.996 39.572 40.676 38v 10642.00 53.4 50.9 59.3 56.6 20.5 20.1 12.000 11.661 35.903 36.949 39V 10643.20 247. 223. 366. 257. 21.7 21.2 12.467 12.101 38.356 39.516 41V 10645.00 58.4 56.0 62.8 60.4 19.4 19,1 11.255 11.039 35.760 36.459 42V. 10646.20 279. 263. 288. 272. 23.8 23.1 13.424 12.956 35.116 36.385 43V 10647.00 240. 227. 249. 236. 23.6 22.9 13.374 12.822 39.599 41.304 44V 10648.00 0.456 0.352 0.724 0.565 16.0 15.2 9.095 8.606 49.353 52.159 9.2 9.6 52.8 55.4 10.6 10.9 50.2 51.6 9.9 10.2 45.8 47.1 14.6 15.0 52.9 54.5 10.2 10.4 46.0 46.9 11.1 11.5 46.2 47.8 8.8 9.2 48.4 50.5 9.9 10,5 59.3 62.6 40,321 106.743 2.647 38.388 101.203 2.636 46.488 124.652 2.681 44.952 119.339 2.655 46,820 127.290 2.719 43.073 114.160 2.650 43.260 114.437 2.645 47.891 128,887 2.691 Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Vertical Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Uncorrected Filtrate Corrected Filtrate Oil UncorTected Corrected Sample millidarcys P~osity, Volume. Water Saturation, Water Saturation, Saturation, Saturation, Total Saturation, Total Saturation, Grain Dry Grain Sample Depth. Klinkenber~l I to ,Nr percent cc percent PV percent PV percent PV percent F'V percent F'V percent PV Volume, Weight, Density, .Numbe~ feet 800psi I 3500psiI 800psi I 3500psi 800 psi13500 psi 800psi 13500psi 800psiI 3500psi 800psi] 3500psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 psi cc grams gm/cc 45v 10649.20 127. 121. 134. 46'v 10650.00 46.1 43.8 50.3 47v 10651.00 241. 220. 255. 48v 10651.85 244. 214. 271. 49v 10653.00 106. 100. 113. 50v 10654.00 286. 272. 296. 51v 10655.20 272. 257. 283. 52v 10656.00 184. 171. 270. 53v 10657.00 1.69 1.47 2.38 54v 10658.20 60.6 56.5 67.0 55v 10659.20 83.0 77.6 90.2 56v 10660.00 33.4 30.6 38.1 57v 10662.00 27.7 25.0 32.5 58V 10663.00 27.3 25.6 30.9 59v 10664.00 176. 165. 185. 60v 10665.10 87.8 81.1 95.3 61v 10666.00 59.6 54.8 65.7 62V 10667.00 221. 202. 232. 63v 10668.10 63.1 57.1 69,9 64v 10669.00 140. 131. 149. 65v 10670.40 88.1 82.4 96.2 66v 10671.45 10.5 9.62 12.7 67V 10672.30 31.3 29.4 35.4 68V 10673.00 3.08 2.64 4.08 69v 10674.50 5.25 4.09 7.72 70v 10675.00 25.9 24.3 29.7 71v 10676.00 32.0 28.6 38.8 72v 10677.20 216. 197. 238. 73V 10678.00 410. 379. 422. 74V 10679.00 267. 246. 280. 75V 10680.20 4.77 2.61 8.11 76V 10681.00 219. 204. 228. 77v 10682.00 58.4 53.4 65.3 78v 10683.20 114. 103. 123. 79V 10684.00 356. 333. 367. 80v 10685.00 375. 349. 384. 81v 10686.20 384. 356. 394. 82v 10687.00 372. 346. 382. 83V 10687.90 50.1 46.9 55.2 84v 10689.20 2.99 2.80 3.94 85v 10690.00 24.1 22.8 27.4 129. 23.2 22.5 13.248 12.787 38.063 39.436 38.1 39.4 0.0 0.0 8.0 8.3 46.0 47.7 46.0 47.7 43.925 117.906 2.684 48.0 20.8 20.2 11.862 11.435 48.823 50.643 7.3 7.6 56.2 58.3 45.264 124.102 2.742 234. 26.2 25.5 15.006 14.489 46.593 48.252 9.8 10.1 56.4 58.4 42.372 112.197 2.648 239. 28.8 27.2 10.633 9.844 46.735 50.479 7.1 7.7 53.9 58.2 26.286 69.812 2.656 107. 22.9 22.3 12.931 12.529 42.500 43.862 11.7 12.0 54.2 55.9 43.620 119.565 2.741 281. 25.1 24.4 14.220 13.754 36.900 38.151 36.9 38.2 0.0 0.0 12.2 12.6 49.1 50.7 49.1 50.7 42.533 112.734 2.651 267. 25.6 24.9 14.552 14.063 45.412 46.990 12.4 12.8 57.8 59.8 42.338 112.251 2.651 256. 26.0 25.5 14.842 14.492 47.346 48.489 9.5 9.7 56.8 58.2 42.338 114.081 2.695 2.06 19.1 18.4 11.165 10.656 49.414 51.777 11.1 11.6 60.5 63.4 47.196 130.308 2.761 62.6 23.3 22.7 13.143 12.672 46.557 48.287 9.3 9.7 55.9 58.0 43.175 115.797 2.682 84.6 23.6 22.9 13.447 12.967 48.894 50.706 48.9 50.7 0.0 0.0 7.7 7.9 56.6 58.6 56.6 58.6 43.620 116.984 2.682 35.0 23.2 22.6 13.510 13.043 54.573 56.528 6.8 7.0 61.3 63.5 44.617 120.234 2.695 29.5 23.7 22.8 13.740 13.089 51.602 54.171 5.0 5.2 56.6 59.4 44.216 120.509 2.725 29.0 20.3 19.7 11.550 11.061 47.296 49.388 8.9 9.3 56.2 58.7 45215 127.879 2.828 174. 24.4 23.7 14.008 13.525 44.561 46.155 9.2 9.5 53.8 55.7 43.481 118.330 2.721 88.2 24.8 23.9 13.957 13.280 46.270 48.630 46.3 48.6 0.0 0.0 9.7 10.2 56.0 58.8 56.0 58.8 42.314 115.297 2.725 60.6 23.1 22.3 13.297 12.690 46.072 48.275 9.7 10.2 55.8 58.5 44.228 121.342 2.744 212. 26.8 26.0 14.804 14.179 46.042 48.071 9.5 9.9 55.5 58.0 40.365 107.743 2.669 63.7 25.7 24.8 14.723 14.041 49.376 51.777 8.9 9.3 58.3 61.1 42.540 113.407 2.666 139. 26.4 25.6 14.981 14.362 50.436 52.613 6.0 6.3 56.4 58.9 41.712 111.271 2.668 90.1 24.4 23.7 13.900 13.370 45.652 47.462 45.7 47.5 0.0 0.0 7.3 7.6 52.9 55.0 52.9 55.0 43.051 116.842 2.714 11.7 20.5 19.8 11.395 10.924 48.126 50.204 6.2 6.5 54.3 56.7 44.232 120.361 2.721 33.4 21.6 20.9 12.371 11.869 42.786 44.597 9.0 9.3 51.7 53.9 44.848 120.851 2.695 3.48 18.5 17.9 10.377 9.962 48.549 50.571 7.5 7.8 56.1 58.4 45.697 123.906 2.711 6.08 21.9 21.1 12.592 12.047 45.341 47.394 8.0 8.4 53.4 55.8 44.916 119.992 2.671 27.8 22.2 21.7 12.507 12.155 46.468 47.814 46.5 47.8 0.0 0.0 8.4 8.6 54.8 56.4 54.8 56.4 43.867 116.962 2.666 34.9 25.3 24.4 14.t87 13.561 44.112 46.149 11.3 11.8 55.4 58.0 41.941 117.494 2.801 219. 27.5 26.7 15.504 14.885 38.735 40.343 14.5 15.1 53.3 55.5 40.947 110.088 2.689 392. 27.9 27.1 15.618 15.007 41.712 43.410 12.1 12.6 53.8 56.0 40.276 107.885 2.679 258. 28.4 27.6 15.632 15.060 46.940 48.724 11.3 11.7 58.3 60.5 39.453 105.743 2.680 4.51 24.5 23.6 13.973 13.317 51.124 53.643 51.1 53.6 0.0 0.0 9.5 9.9 60.6 63.6 60.6 63.6 43.059 113.950 2.646 213. 25.7 25.0 14.744 14.190 44.725 46.472 10.0 10.4 54.7 56.9 42.602 114.515 2.688 59.8 24.2 23.5 13.360 12.844 49.798 51.799 10.5 10.9 60.3 62.7 41.812 112.548 2.692 112. 26.1 25.3 14.865 14.242 46.652 48.692 11.4 11.8 58.0 60.5 41.995 113.187 2.695 343. 26.9 26.2 14.824 14.317 43.618 45.162 11.6 12.0 55.2 57.2 40.383 107.818 2.670 359. 26.2 25.5 14.868 14.3~7 44.903 46.372 44.9 46.4 0.0 0.0 9.9 10.3 54.8 56.6 54.8 56.6 41.981 113.836 2.712 366. 26.4 25.7 14.567 14.021 43.876 45.587 10.6 11.0 54.5 56.6 40.583 109.522 2.699 356. 26.8 26.2 15.047 14.586 47.591 49.094 11.2 11.5 58.8 60.6 41.045 109.074 2.657 51.8 21.7 21.0 12.150 11.670 52.628 54.794 8.5 8.9 61.2 63.7 43.792 118.350 2.703 3.69 15.4 14.9 8.737 8.387 42.408 44.179 10.8 11.3 53.3 55.5 47.989 133.16(; 2.775 26.0 18.4 17.9 10.585 10.247 48.475 50.077 48.5 50.1 0,0 0.0 8.8 9.1 57.3 59.2 57.3 59.2 46.942 127.249 2.711 core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Vertical Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Uncorrected Filtrate Corrected Filtrate Oil Uncorrected Corrected Sample millidarcys Porosity. Volume, Water Saturation. Water Saturation. Saturation. Saturation, Total Saturation, Total Saturation, Grain Dry Grain Sample Depth, Klinkenberg I to Air percent cc percent PV percent PV percent PV percent PV percent PV percent PV Volume, Weight, Density, Numbel feet 800psi I 3500psiI 800psi I 3500psi ,800psi13500ps' 800psi 1350Opsi 800psiI 3500psi 800psiI 3500psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 psi cc ~lrams gm/cc 87V 10692.00 68.4 64.3 72.4 68.1 18.9 18.3 10.726 10.303 45.269 47.127 8.7 9.0 54.0 56.2 46.068 124.244 2.697 88V 10693.80 0.564 0.517 0.744 0.682 11.1 10.7 6.438 6.214 53.009 54.918 9.5 9.8 62.5 64.8 51.643 151.056 2.925 89V 10695.00 0.033 0.0002 0.052 0.0004 7.8 5.8 4.463 3.235 67.496 0.000 18.7 0.0 86.2 0.0 52.931 145.431 2.748 90V 10696.10 27.1 25.4 31.0 29.1 22.0 21.3 12.676 12.177 42.873 44.632 42.9 44.6 0.0 0.0 10.6 11.1 53.5 55.7 53.5 55.7 44.897 120.321 2.680'11 91V 10697.00 9.91 9.15 12.0 11.1 19.7 19.1 11.233 10.794 48.129 50.085 9.6 10.0 57.7 60.0 45.674 122.029 2.672 93V 10699.00 18.6 17.5 21.2 20.1 t8.7 18.1 10.814 10.368 43.345 45.208 13.0 13.5 56.3 58.7 46.902 132.127 2.817 94V 10700.00 10.7 9.8 12.9 11.8 19.7 19.1 11.243 10.826 44.573 46.287 10.1 10.5 54.6 56.7 45.941 123.047 2.678 95V 10701.00 23.0 21.4 26.4 24.6 20.7 20.0 11.845 11.348 45.393 47.379 45.4 47.4 0.0 0.0 8.2 8.6 53.6 56.0 53.6 56.0 45.507 122.584 2.694 96V 10702.10 5.66 5.05 7.01 6.27 18.5 17.8 10.437 10.015 43.589 45~424 14.0 14.6 57.6 60.0 46.113 t24.642 2.703 97V 10703.00 35.9 32.9 40.9 37.5 22.4 21.7 1Z820 1Z301 48.847 50.908 11.1 11.5 59.9 62.5 44.365 119.184 2.686 99V 10705.05 8.33 7.40 10.2 9.00 18.5 17.8 8.425 8.071 51.149 53.390 10.9 11.4 62.1 64.8 37.167 101.958 2.743 IOOV 10706.45 221. 204. 232. 215. 25.2 24.6 14.418 13.935 45.970 47.562 46.0 47.6 0.0 0.0 8.6 8.~, 54.5 56.4 54.5 56.4 42.740 t14.287 2.674 101V 10707.00 197. 185. 206. 193. 24.5 23.8 13.783 13.324 47.265 48.894 10.8 11.1 58.0 60.0 42.546 114.849 2.699 102V 10708.00 176. 166. 185. 174. 23.8 23.2 13.655 13.218 45.512 47.015 11.0 11.4 56.5 58.4 43.767 116.299 2.657 103V 10709.00 168. 159. 175. 166. 22.7 22.2 12.816 12.443 43.725 45.035 13.8 14.2 57.5 59.2 43.587 119.334 2.738 104V 10710.40 29.5 26.5 33.2 30.0 21.5 20.7 12.316 11.759 49.841 52.200 11.4 11.9 61.2 64.1 44.992 120.755 2.684 106V 10712.00 101. 95.2 107. 101. 21.5 20.8 12.425 11.955 51.278 53.295 39.8 41.3 11.5 11.9 11.9 12.3 63.1 65.6 51.6 53.7 45.383 125.993 2.776 107V 10713.00 160. 147. 168. 156. 23.4 22.8 13.188 12.723 49.835 51.658 9.4 9.8 59.3 61.4 43.130 118.065 2.737 108V 10714.00 59.3 55.9 63.0 59.6 19.7 19.1 8.000 7.709 50.435 52.341 9.8 10.2 60.3 62.5 32.579 92.311 2.833 109V 10715.00 110. 103. 119. 112. 23.0 22.4 13.093 12.665 53.802 55.622 11.9 12.3 65.7 67.9 43.907 121.889 2.776 110V 10716.00 41.8 38.3 47.6 43.8 23.1 22.4 12.866 12.378 51.555 53.589 51.6 53.6 0.0 0.0 11.2 11.6 62.7 65.2 62.7 65.2 42.839 115.311 2.692 111V 10717.30 10.1 7.67 12.9 10.0 21.1 20.4 11.974 11.460 51.759 54.078 12.5 13.1 64.3 67.2 44.838 120.787 2.694 112V 10718.00 206. 194. 216. 203. 25.0 24.4 14.211 13.724 53.171 55.060 6.5 6.7 59.7 61.8 42.562 114.000 2.678 113V 10720.20 113. 106. 122. 114. 24.1 23.3 13.749 13.210 50.257 52.311 11.0 11.4 61.2 63.7 43.410 115.703 2.665 114V 10722.30 134. 126. 143. 134. 24.2 23.5 13.703 13.167 50.144 52.186 11.2 11.6 61.3 63.8 42.961 117.035 2.724 ,I 115V 10724.00 57.0 52.1 63.2 58.0 22.5 21.8 12.684 12.155 54.651 57.030 41.4 43.2 13.2 13.8 9.4 9.8 64.0 66.8 50.8 53.0 43.619 116.484 2.670 116V 10725.00 38.2 35.1 42.9 39.5 22.1 21.3 12.495 11.952 47.992 50.171 10.0 10.4 57.9 60.6 44.133 119.127 2.699 117V 10726.00 1.30 0.906 2.05 1.45 19.1 18.4 10.793 10.262 48.240 50.738 10.3 10.9 58.6 61.6 45.594 123.383 2.706 118V 10727.00 4.33 3.78 5.52 4.81 t 8.7 17.9 10.575 10.002 43.256 45.733 11.2 11.9 54.5 57.6 45.889 121.787 2.654 119V 10728.10 23.6 21.9 27.1 25.2 21.2 20.5 11.971 11.477 44.216 46.121 7.8 8.1 52.0 54.3 44.491 119.246 2.680 120V 10729.00 64.7 59.9 70.6 65.4 22.0 21.4 12.526 12.075 45.035 46.715 45.0 46.7 0.0 0.0 9.3 9.7 54.4 56.4 54.4 56.4 44.420 118.773 2.674 121V 10730.00 32.6 29.7 36.2 33.1 18.9 18.3 10.765 10.331 47.088 49.067 9.2 9.6 56.3 58.7 46.087 131.216 2.847 122V 10731.05 0.541 0.299 0.992 0.603 16.8 15.9 6.603 6.192 44.941 47.919 19.6 20.9 64.6 68.9 32.739 86.801 2.651 123V 10732.35 8.31 7.80 10.10 9.50 15.3 14.8 8.771 8.468 40.491 41.937 16.3 16.8 56.8 58.8 48.681 131.190 2.695 124V 10733.00 2.86 2.50 3.50 3.10 12.8 12.4 7.305 7.030 38.111 39.605 11.3 11.8 49.4 51.4 49.704 135.280 2.722 125V 10735.00 2.08 1.90 2.70 2.40 12.4 11.9 7.182 6.8~8 40.531 42.388 40.5 42.4 0.0 0.0 7.7 8.0 48.2 50.4 48.2 50.4 50.698 138.626 2.734 127V 10736.00 0.0032 0.0015 0.0057 0.0026 5.2 4.7 2.164 1.940 27.015 30.139 18.7 20.9 45.7 51.0 39.245 111.658 2.845 129V 10736.80 16.5 14.8 19.0 17.1 17.0 16.3 9.755 9.298 38.058 39.930 11.3 11.9 49.4 51.8 47.706 125.995 2.641 130V 10738.15 0.157 0.031 0.232 0.056 8.2 7.3 4.723 4.191 61.637 69.462 61.6 69.5 0.0 0.0 12.1 13.6 73.7 83.1 53.038 148.774 2.805 131V 10739.00 18.7 17.7 21.7 20.6 17.1 16.5 9.677 9.300 34.928 36.344 7.9 8.2 42.8 44.5 47.005 126.952 2.701 132V 10740.20 #DIV/0! #DIV/0! 0.000 0.000 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! 0.000 0.000 #DIV/0! Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Vertical Dean Stark Samples British Petroleum File: DAL-97369 13-06A Well Permeability, Pore Uncorrected Filtrate Corrected Filtrate Oil Uncorrected Corrected Sample millidarcys Porosity, Volume, Water Saturation, Water Saturation, Saturation, Saturation, Total Saturation, Total Saturation, Grain Dry Grain Sample Depth, Klinkenberg I to Air percent cc percent PV percent PV percent PV percent PV percent PV percent PV Volume, Weight, Density, Numbel feet 800psi I 3500psiI 800psi i 3500psi 1800psi13500ps 800psi 13500psi, 800psiI 3500psi 800psiI 3500psi 800 psi13500 psi 800 psi13500 psii 800 psi13500 psi 800 psi13500 psi cc grams gm/cc 133V 10741.10 134V 10742.00 135V 10743.20 26.7 19.1 31.0 136V 10744.00 107. 98.3 115. 137V 10745.00 151. 135. 159. 138V 10746.30 157. 147. 165. 139V 10747.00 19.0 17.2 22.8 140V 10748.35 141V 10749.30 15.3 13.9 18.2 142V 10750.00 176. 158. 186. 144V 10752.00 61.4 58.2 66.8 145V 10753.00 200. 190. 209. 147V 10755.70 56.3 52.7 61.5 148V 10756.50 54.8 50.5 60.1 150V 10758.30 191. 176. 199. 151V 10759.10 176. 165. 184. 152V 10760.00 173. 162. t80. 153V 10761.00 73.8 68.9 79.1 154V 10762.00 1.89 1.50 2.82 155V 10763.00 2.31 2.20 2.80 156V 10764.00 296. 279. 303. 157V 10765.30 392. 366. 398. 158V 10766.00 395. 364. 410. 159V 10767.00 266. 237. 275. 160V 10768.00 271. 256. 281. 161V 10769.00 197. 189. 205. 162V 10770.00 107. 101. 114. 163V 10771.30 231. 213. 244. 164V 10772.00 154. 140. 164. 165V 10773.00 9.52 7.60 13.2 166V 10774.10 147. 139. 155. 167V 10775.00 117. 109. t24. 168V 10776.00 182. 171. 191. 169V 10777.10 54.5 48.4 61.7 170V 10778.00 561. 521. 572. 171V 10779.00 87.2 78.6 96.7 172V 10780.30 357. 332. 369. 173V 10781.60 388. 357. 399. 174V 10782.00 560. 525. 574. 175V 10786.10 214. 192. 226. 176V 10787.00 497. 385. 536. #DIV/0! #DIVI0! 0.000 0.000 #DIV/0! #DIV/0! #DIVI0! #DIV/O! #DIV/0! #DIV/O! 0.000 0.000 #DIVI0! #DIV/0! 0.000 #DIVI0! 0.000 #DIVI0! #DIV/0! 0.0 0.000 0.0OO #DIVI0! 22.6 17.4 16.7 7.569 7.174 44.915 47.388 44.9 47.4 0.0 0.0 9.0 9.5 53.9 56.9 53.9 56.9 35.862 104.449 2.913~ 106. 22.9 22.1 t 3.185 12.605 45.365 47.454 10.2 10.7 55.6 58.2 44.323 123.771 143. 23.7 22.7 9.936 9,376 48.437 51.329 154. 23.9 23.2 13.245 12.755 45.636 47.387 20.7 22.3 21.6 t2,865 12.310 46.645 48.746 #DIVlO #DIVlO! 0.000 0.000 #DIVlO! #DIVIO! 16.6 20.5 19.8 11.221 10,706 47.769 50.068 167. 25.6 24.6 10.755 10.209 45.611 48.051 63.5 20.9 20.2 11.451 11.015 37.083 38.551 198. 23.3 22.7 t3.391 12.962 40.768 42.117 9.3 9.8 57.7 61.2 10.6 11.0 56.2 58.4 10.7 11.1 57.3 59.9 #DIVI0! #DIV/O! #DIV/0! #DIV/0! 10.4 10.9 58.2 61.0 10.1 10.6 55.7 58.7 13.9 14.4 51.0 53.0 11.9 12.~ 52.7 54.4 31.973 88.720 2.775 42.172 115.779 2.745 44.756 126.620 2.829 0.000 0.000 #DIVI0! 43.470 119.369 2.746 31.304 86.463 2.762 43.426 119.186 2.745 44.060 t 19.040 2.702 57.7 22.3 21.6 8.462 8.123 41.500 43.233 41.5 43.2 0.0 0.0 13.6 14.2 55.1 57.4 55.1 57.4 29.541 79.944 2.706 55.6 22.7 22.1 9.793 9.425 46.718 48.540 12.6 13.1 59.3 61.6 33.255 89.584 2.694 184. 24.9 24.2 14.383 13.832 48.125 50.042 48.1 50.0 0.0 0.0 13.3 13.9 61.5 63.9 61.5 63.9 43.335 t18.360 2.731 173. 24.0 23.3 13.899 13.398 47.200 48.966 11.7 12.1 58.9 61.1 44.067 t21.734 2.762 169. 23.8 23.2 13.569 13.109 52.358 54.197 11.3 11.7 63.7 65.9 43.381 118.034 2.721 74.0 21.0 20.4 12.089 11.679 19.198 19.872 45.9 47.5 65.1 67.4 45.575 123.169 2.703 2.28 17.0 16.4 9.732 9.370 47.516 49.356 17.8 18.5 65.3 67.8 47.636 130.611 2.742 2.70 13.2 12.7 7.814 7.453 49.570 51.970 49.6 52.0 0.0 0.0 14.8 15.5 64.3 67.5 64.3 67.5 51.232 151.997 2.967 285. 23.2 22.5 13.351 12.888 44.308 45.899 22.9 23.8 67.3 69.7 44.320 121.710 2.746 373. 24.1 23.4 t3.618 13.122 47.248 49.035 16.8 17.4 64.1 66.5 42.973 118.134 2.749 377. 24.4 23.7 14.061 13.542 49.480 51.374 16.0 16.6 65.5 68.0 43.483 119.190 2.741 246. 25.5 24.5 10.551 9.990 47.475 50.144 17.0 17.9 64.4 68.1 30.864 82.168 2.662 266. 24.3 23.6 13.782 13.291 48.463 50.253 48.5 50.3 0.0 0.0 15.2 15.8 63.7 66.0 63.7 66.0 43.016 117.948 2.742 197. 23.1 22.4 10.027 9.689 51.431 53.225 16.9 17.5 68.4 70.8 33.474 91.443 2.732 108. 22.0 21.3 12.539 12.029 46.302 48.265 15.9 16.6 62.2 64.9 44.457 126.114 2.837 226. 25.9 25.2 14.601 14.041 45.831 47.660 19.5 20.3 65.3 67.9 41.748 112.797 2.702 149. 25.3 24.5 14.312 13.711 43.970 45.897 19.5 20.3 63.4 66.2 42.226 111.754 2.647 10.5 22.8 22.1 13.042 12.576 45.844 47.540 45.8 47.5 0.0 0.0 22.8 23.6 68.6 71.1 68.6 71.1 44.270 119.043 2.689 147. 24.1 23.5 13.774 13.301 41.909 43.400 19.8 20.5 61.7 63.9 43.381 117.053 2.698 116. 23.9 23.3 13.738 13.283 45.929 47.501 21.9 22.6 67.8 70.1 43.805 117.854 2.690 180. 24.9 24.3 14.171 13.727 45.534 47.007 20.3 21.0 65.9 68.0 42.827 115.928 2.707 55.1 23.9 23.2 13.557 13.044 52.068 54.118 17.0 17.7 69.1 71.8 43.071 114.981 2.670 532. 27.9 27.0 11.843 11.329 42.261 44.178 42.3 44.2 0.0 0.0 22.0 23.0 64.3 67.2 64.3 67.2 30.656 81.537 2.660 87.6 26.0 25.2 14.815 14.2~)0 50.631 52.750 14.2 14.8 64.9 67.6 42.234 111.981 2.651 344. 26.5 25.9 14.960 14.488 47.232 48.771 t9.6 20.2 66.8 69.0 41.479 116.588 2.8tl 368. 26.5 25.7 15.049 14.444 44.667 46.537 20.7 21.5 65.3 68.1 41.672 116.903 2.805 540. 26.0 25.4 14.875 14.413 42.159 43.511 19.1 19.7 61.3 63.2 42.268 119.862 2.836 204. 25.4 24.6 14.431 13.852 39.085 40.720 0.9 1.0 38.1 39.7 25.6 26.6 64.7 67.4 26.5 27.6 42.398 115.236 2.718 409. 26.5 25.5 14.317 13.622 45.523 47.847 t9.9 20.9 65.4 68.8 39.721 112.246 2.826 Core Laboratories SUMMARY OF ROUTINE CORE ANALYSES RESULTS Vertical Dean Stark Samples British Petroleum File: DAL-97369 1 3-06A Well Permeability, Pore Uncorrected Filtrate Corrected Filtrate Oil Uncorrected Corrected Sample millidarcys Porosity, Volume, Water Saturation, Water Saturation, Saturation, Saturation, Total Saturation, Total Saturation, Grain Dry Grain Sample Depth, Klinkenberg I to Air percent cc percent PV percent PV percent PC percent PV percent Pc percent Pc Volume, Weight, Density, Numbe~ feet 800psi I 3500psiI 800psi I 3500psi 800psi13500ps~ 800psi 13500psi 800psiI 3500psi 800psiI 3500psi 800 psi J 3500 psi 800 psi13500 psi 800 psi13500 psi 800 psi13500 psi cc grams gm/cc 177V 10788.00 131. 113. 144. 125. 27.5 26.6 15.764 14.998 45.717 48.050 17.9 18.8 63.6 66.9 41.474 111.560 2.690 179V 10790.10 419. 380. 429. 391. 26.7 25.9 15.094 14.496 42.348 44.095 21,1 22.0 63.5 66.1 41.497 112.999 2.723 180V 10791.00 694. 619, 706. 633. 29.1 28.2 16.412 15.704 40.783 42,623 32.1 33.5 8.7 9.1 24,1 25.2 64.9 67.8 56.2 58.7 40.006 105.328 2.633 181V 10792.00 577. 471. 590. 484. 29.2 27.6 10.183 9.445 39.996 43.125 20.7 22.3 60.7 65,4 24.717 67.416 2.7271'1,' 182V 10793.30 91,8 75.3 104. 84.9 26.6 25.6 14.978 14.253 50.357 52.918 16.0 16.8 66.3 69.7 41.396 112.336 2.714 183V 10794.00 274. 238. 284. 248. 25,6 24.8 14.510 13.874 47,442 49.617 13.1 13.8 60.6 63.4 42.063 113.199 2.691 184V 10795,00 447, 385, 459. 398. 28.0 27.1 15,682 14.931 49.741 52.242 18.2 19.1 67,9 71.3 40.263 108.447 2.693 185V 10796.20 1530, 1640, 2160. 1770. 28.8 27.8 16.398 15.601 39.312 41.320 39.3 41.3 0.0 0.0 22.6 23.7 61.9 65.1 61.9 65, t 40.460 110.137 2.722 186V 10797.00 722. 662. 736. 187V 10798.00 415. 371. 437. 188V 10799.25 1050. 941. 1060. 189V 10800.00 739. 653. 752. 190V 10801,00 171. 154. 185. 191V 10802.10 158. 147. 170. 192V 10803.00 280. 259. 295. 194V 10805.60 111. 90.1 132. 195V 10806.00 584. 558. 590. 196V 10807.00 2880, 2470, 2920. 2500. 29.2 27,9 16.573 15.555 45.169 48.127 204V 10822.60 851. 824. 872, 827. 26,8 25.9 10.736 10.276 38.846 40.585 677. 28.7 27.7 16.597 15.795 45.342 47.643 21.9 23.0 67.2 70.7 41.163 112.791 2.740 393. 29.0 27.8 11.166 10.525 45.789 48.580 17.5 18.6 63.3 67.2 27.324 73.845 2.703 948. 28.8 27.9 16.301 15.638 43.080 44.907 20.5 21.3 63.5 66.2 40.359 109.948 2.724 667. 28.5 27.5 16.429 15.645 50.315 52.837 13.5 14.1 63.8 67.0 41.182 112.235 2.725 167. 26.3 25.4 14.894 14.228 50.649 53.018 50.6 53.0 0.0 0.0 16.9 17.7 67.5 70.7 67.5 70.7 41.695 113.528 2.723 158. 26.2 25.5 14.801 14.252 43.746 45.429 21.6 22.5 65.4 67.9 41.668 t10.489 2.652 273. 26.9 26.2 15.552 14.998 43.205 44.803 19.1 t9.8 62.3 64.6 42.2t2 111.698 2.646 100. 21.7 20,9 8.911 8.512 34.203 35.806 23.5 24.6 57.7 60.4 32.164 85.079 2.645 565. 23.6 23.0 13.660 13.227 29.308 30.267 29.3 30.3 0.0 0.0 31.9 33.0 61.2 63.2 61.2 63.2 44.338 t17.847 2.658 19.2 20.5 64.4 68.6 40,136 t06,288 2.648 23.4 24.5 62.3 65.1 29.373 79.205 2.697 Core Laboratories 10000 1000 lO0 lO 1 0.1 o.01 0.001 0.0o01 PERMEABILITY TO AIR VERSUS POROSITY 13-06A WELL 0 6 12 18 24 30 36 Porosi~,percent · 800 psi u 3500 psi Core Laboratories WATER SATURATION VERSUS POROSITY '13-06A WELL 0 6 12 18 24 30 36 Porosity, percent 800 psi · 3500 psi Corrected 800 psi × Corrected 3500 psi Core Laboratories OIL SATURATION VERSUS POROSITY 13-06A WELL 0 6 12 18 24 30 36 Porosity, percent 800 psi .~ 3500 psi Core Laboratories L ~ OIL SATURATION VERSUS DEPTH 13-06AWELL 10500 10600 10700 10800 10900 Depth, feet · 800 psi ~ 3500 psi Core Laboratories ARCO Alaska, Inc. File: DAL-97369 Section 5 GRAIN DENSITY DATA Core Laboratories SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples British Petroleum 13-06A Well Core Number Sample Number Sample Depth, feet Dry Grain Weight, Volume, ~lm cc Grain Density, sm/cc Sample Length, cm 1 lA ! 2A 1 3A 1 4A I 5A I 6A 1 7A I 8A I 9A I 10A 1 11A I 12A 1 13A I 14A 1 15A 1 16A 1 17A 1 18A 1 19A 2 20A 2 21A 2 22A Sample Diameter, cm File: DAL-97369 10523.10 105.098 39.729 2.645 3.897 3.760 10524.10 109.011 40.174 2.713 3.902 3.791 10525.10 105.956 39.422 2.688 3.796 3.792 10526.10 91.665 34.643 2.646 3.824 3.797 10527.10 92.565 34.640 2.672 3.857 3.761 10528.10 94.319 35.238 2.677 3.922 3.751 10529.10 92.582 34.662 2.671 3.863 3.745 10530.10 95.719 35.614 2.688 3.852 3.796 10531.10 95.092 35.440 2.683 3.850 3.797 10532.10 91.386 34.064 2.683 3.828 3.756 10533.10 94.043 35.021 2.685 3.646 3.798 10534.10 93.800 34.962 2.683 3.805 3.797 10535.10 93.396 34.527 2.705 3.647 3.752 10536.10 94.299 35.119 2.685 3.821 3.797 10537.10 94.176 34.960 2.694 3.837 3.758 10538.10 94.759 35.168 2.694 3.889 3.744 10539.10 98.210 36.276 2.707 3.823 3.798 10540.10 98.383 36.003 2.733 3.898 3.757 10541.10 100.662 36.630 2.748 3.800 3.800 10624.10 108.705 37.440 2.903 3.857 3.757 10625.10 97.838 34.865 2.806 3.841 3.807 10626.10 89.227 32.871 2.714 3.798 3.744 Sample Area, cm2 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 .104 .287 .293 .323 .110 .051 .015 .317 .323 .080 .329 .323 .056 .323 .092 .009 .329 .086 .341 .086 .383 .009 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet 2 23A 2 24A 2 25A 2 26A 2 27A 2 28A 2 29A 2 30A 2 31A 2 32A 2 33A 2 34A 2 35A 2 36A 2 37A 2 38A 2 39A 2 40A 2 41A 2 42A 2 43A 2 44A 2 45A 2 46A 2 47A 2 48A 1 O627.10 1O628.2O 10629.10 10630.60 10631.10 10632.10 10633.30 10634.30 10635.10 10636.10 10637.30 10638.10 10639.10 10640.60 10641.40 10642.10 10643.30 10644.15 10645.10 10646.30 1 O647.10 1 O648.10 10649.30 10650.10 10651,10 10651.95 Dh/ Weight, 91.367 92.815 88.716 88.317 89.089 83.116 90.136 90.819 88.373 83.131 83.500 86.549 83.712 81.468 87.653 93.256 88.884 112.999 95.922 92.921 86.174 96.119 91.573 91.190 85.620 Grain Volume, CC 33.553 32.945 33.177 33.450 32.097 31.299 32.520 33.961 33.422 31.510 31.627 32.725 31.728 30.913 33.202 34.900 33.301 41.536 35.606 33.800 32.668 35.764 34.012 33.519 31.920 Grain Density, gm/cc 2.723 2.817 2.674 2.640 2.776 2.656 2.772 2.674 2.644 2.638 2.640 2.645 2,638 2.635 2,640 2.672 2.669 2.720 2.694 2.749 2,638 2.688 2.692 2.721 #DIV/0! 2.682 Sample Length, cm Sample Diameter, cm Sample Area, cm2 3.847 3.837 3.861 3.847 3.829 3.873 3.813 3.875 3.805 3.852 3,858 3.872 3.825 3.892 3.780 3.889 3.878 3.842 3.881 3.856 3.866 3.803 3.908 3.814 3.818 3.792 3.748 3.758 3.771 3.794 3.783 3.807 3.753 3.797 3.771 3.792 3.761 3.796 3.763 3.808 3.759 3.756 3.810 3.765 3.798 3.759 3.801 3.765 3.816 3.787 11.293 11.033 11.092 11.169 11.305 11.240 11.383 11.062 11.323 11.169 11.293 11.110 11.317 11.121 11.389 11.098 11.080 11.401 11.133 11.329 11.098 11.347 11.133 11.437 0.000 11.264 Core Laboratories SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples British Petroleum 13-06A Well File: DAL-97369 Core Number Sample Number Sample Depth, feet Dry Weight, Grain Volume, CC Grain Density, ~lm/cc Sample Length, cm Sample Diameter, cm Sample Area, cm2 2 49A 2 50A 2 51A 2 52A 2 . 53A 2 54A 2 55A 2 56A 3 57A 3 58A 3 59A 3 60A 3 61A 3 62A 3 63A 3 64A 3 65A 3 66A 3 '67A 3 68A 3 69A 3 70A 3 71A 3 72A 3 73A 3 74A 10653.10 1 O654.10 10655.30 10656.10 10657.4O 10658.30 10659.30 10660.00 10662.10 10663.10 10664.10 10665.20 10666.10 10667.10 10668.20 10669.10 10670.50 10671.55 10672.40 10673.10 10674.30 10675.10 10676.10 10677.30 10678.10 10679.10 90.975 84.949 86.646 84.659 120.000 94.208 87.399 87.467 89.752 92.118 88.984 86.406 103.481 82.610 84.049 84.292 89.091 96.114 89.357 90.865 88.207 88.960 94.175 83.873 79.295 84.463 33.224 31.952 32.416 31.805 41.785 34.560 32.198 32.502 32.856 33.296 32.683 31.539 35.081 30.658 31.552 31.473 32.975 35.311 33.205 33.603 32.772 33.346 33.200 30.961 29.661 30.910 2.738 2.659 2.673 2.662 2.872 2.726 2.714 2.691 2.732 2.767 2.723 2.740 2.950 2.695 2:664 2.678 2.702 2.722 2.691 2.704 2.692 2.668 2.837 2.709 2.673 2.733 3.848 3.864 3.862 3.822 3.862 3.859 3.382 3.838 3.800 3.834 3.789 3.850 3.815 3.815 3.784 3.861 3.832 3.821 3,835 3.856 3.886 3.939 3.872 3.774 3.840 3.805 3.765 3.759 3.811 3.767 3.793 3.804 3.762 3.764 3.792 3.776 3.796 3.771 3.807 3.766 3.805 3.770 3.807 3.777 3.770 3.773 3.776 3.773 3.768 3.776 3.757 3.798 11.133 11.098 11.407 11.145 11.299 11.365 11.115 11.127 11.293 11.198 11.317 11.169 11.383 11.139 11.371 11.163 11.383 11.204 11.163 11.181 11.198 11.181 11.151 11.198 11.086 11.329 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet 3 75A 3 76A 3 77A 3 78A 3 79A 3 80A 3 81A 3 82A 3 83A 3 84A 3 85A 3 86A 3 87A 3 88A 3 89A 3 90A 3 91A 3 92A 3 93A 3 94A 3 95A 3 96A 3 97A 3 98A 3 99A 3 100A Dry Grain Weight, Volume, ~lm co Grain Density, ~lm/cc Sample Length, cm Sample Diameter, Gm 10680.30 80.617 30.306 2.660 3.825 3.755 10681.10 87.770 32.672 2.686 3.818 3.811 10682.10 85.776 32.240 2.661 3.782 3.795 10683.30 87.405 31.726 2.755 3.819 3.774 10684.10 80.059 30.183 2.652 3.855 3.773 10685.10 83.633 31.273 2.674 3.869 3.768 10686.30 83.978 31.257 2.687 3.832 3.804 10687.10 82.067 30.885 2.657 3.887 3.778 10688.00 87.905 32.274 2.724 3.846 3.758 10689.30 103.828 37.396 2.776 3.812 3.800 10690.10 96.597 35.716 2.705 3.892 3.768 10691.30 111.917 41.366 2.706 3.777 3.789 10692.10 95.819 35.471 2.701 3.894 3.905 10693.90 106.573 37.249 2.861 3.862 3.782 10695.10 104.183 38.104 2.734 3.830 3.744 10696.20 89.204 33.322 2.677 3.831 3.757 10697.10 91.847 34.097 2.694 3.842 3.769 10698.25 88.925 33.177 2.680 3.778 3.782 10699.10 95.972 34.678 2.768 3.793 3.792 10700.10 94.441 35.408 2.667 3.829 3.771 10701.10 91.858 34.323 2.676 3.798 3.796 10702.20 96.182 36.040 2.669 3.920 3.769 10703.10 91.849 34.662 2.650 3.785 3.773 10704.40 97.568 35.777 2.727 3.865 3.756 10705.15 94.168 35.059 2.686 3.880 3.775 10706.55 88.134 32.613 2.702 3.811 3.801 Sample Area, Gm2 11.074 11.407 11.311 11.186 11.181 11.151 11.365 11.210 11.092 11.341 11.151 11.276 11.977 11.234 11.009 11.086 11.157 11.234 11.293 11.169 11.317 11.157 11.181 11.080 11.192 11.347 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 4 4 4 4 4 4 4 4 4 4 4 Sample , Number 101A 102A 103A 104A 105A 106A 107A 108A 109A 110A 111A 112A 113A 114A 115A 116A 117A 118A 119A 120A 121A 122A 123A 124A 125A 126A Sample Depth, feet Dry Weight, . ~lm Grain Grain Volume, Density, cc sm/cc Sample Length, cm 10707.10 87.945 32.514 2.705 3.898 10708.30 87.038 32.571 2.672 3.794 10709.10 97.515 34.569 2.821 3.899 10710.50 89.868 33.420 2.689 3.801 10711.65 87.345 32.603 2.679 3.819 10712.10 90.051 33.275 2.706 3.810 10713.10 88.882 32.730 2.716 3.827 10714.10 104.058 35.873 2.901 3.921 10715.10 84.947 31.960 2.658 3.799 10716.10 89.781 33.559 2.675 3.834 10717.40 93.784 35. 367 2.652 3. 824 10718.10 85.452 31.985 2.672 3.807 10719.10 87. 304 32. 360 2.698 3. 852 10720.30 88.526 32.517 2.722 3.827 10722.50 86.637 31.993 2. 708 3. 756 10724.10 89.205 33.106 2.695 3.774 10725.10 99.862 34.965 2.856 3.846 10726.10 92.973 34. 830 2.669 3.813 10727.10 92.447 34.598 2.672 3.844 10728.20 90.627 33.611 2.696 3.842 10729.10 95.576 34.308 2.786 3.832 10730.10 91.978 33.750 2.725 3.784 10731.15 94.793 35.671 2.657 3.840 10732.65 99.360 36.771 2.702 3. 387 10733.10 99.865 37.049 2.696 3. 802 10734.65 116.316 40.717 2.857 - Sample Diameter, cm Sample Area, cm2 3.764 3.793 3.772 3.777 3.760 3.796 3.784 3.766 3.776 3.775 3.794 3.788 3.755 3.787 3.749 3.787 3.772 3.789 3.752 3.786 3.753 3.797 3.773 3.765 3.760 -- 11.127 11.299 11.175 11.204 11.1 04 11.317 11.246 11.139 11.198 11.192 11.305 11.27O 11.074 11.264 11.039 11.264 11.175 11.276 11. O56 11.258 11.062 11.323 11.181 11.133 11.104 - Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet 4 127A 4 128A 4 129A 4 130A 4 131A 4 132A 4 133A 4 134A 4 135A 4 136A 4 137A 4 138A 4 139A 4 140A 4 141A 4 142A 4 143A 4 144A 4 145A 4 146A 4 147A 4 148A 4 149A 4 150A 4 151A 4 152A 10735.10 1O736.25 1O736.9O 10738.25 10739.10 10740.30 10741.30 10742.10 10743.30 10744.10 10745.10 10746.40 10747.10 10748.45 10749.40 10750.10 10751.60 10752.15 10753.10 10754.20 10755.70 10756.75 10757.40 10758.40 10759.20 10760.10 Dry Weight, ~lm 117.943 103.547 98.513 114.008 93.838 116.540 109.947 124.364 94.946 97.536 95.208 92.165 92.917 93.491 94.700 92.417 93.228 87.522 87.904 86.562 90.136 ' 87.060 89.182 90.568 Grain Volume, cc 41.188 38.995 37.298 41.619 34.871 41.365 41.360 40.809 33.730 33.988 33.728 33.919 33.650 33.373 34.251 33.998 34.195 32.243 32.541 32.436 32.520 31.580 32.051 33.138 Grain Density, gm/cc 2.864 2.655 2.641 2.739 2.691 2.817 2.658 3.047 2.815 #DIV/0! #DIV/0! 2.870 2.823 2.717 2.761 2.801 2.765 2.718 2.726 2.714 2.701 2.669 2.772 2.757 2.783 2.733 Sample Length, cm Sample Diameter, cm Sample Area, cm2 3.810 3.696 3.887 3.788 3.809 3.882 3.829 3.897 3.824 3.830 3.859 3.833 3.888 3.856 3.871 3.869 3.875 3.749 3.821 3.833 3.813 3.847 3.829 3.809 3.819 3.748 3.801 3.793 3.786 3.803 3.767 3.811 3.765 3.798 3.796 3.750 3.808 3.809 3.752 3.757 3.796 3.768 3.762 3.771 3.807 3.789 3.757 3.806 11.455 11.033 11.347 11.299 11.258 11.359 11.145 11.407 11.133 0.000 0.000 11.329 11.317 11.045 11.389 11.395 11.056 11.086 11.317 11.151 11.115 11.169 11.383 11.276 11.086 11.377 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, Weight, feet 4 153A 4 154A 4 155A 4 156A 4 157A 4 158A 4 159A 4 160A 4 161A 4 162A 4 163A 4 164A 4 165A 4 166A 4 167A 4 168A 4 169A 4 170A 4 171A 4 172A 4 173A 4 174A 5 175A 5 176A 5 177A 5 178A Grain Volume, cc Grain Density, sm/cc Sample Length, cm Sample Diameter, cm 10761.10 94.277 34.278 2.750 3.885 3.755 10762.10 102.081 37.019 2.758 3.808 3.799 10763.10 104.078 36.211 2.874 3.862 3.766 10764.10 95.538 34.298 2.786 3.874 3.798 10765.40 91.082 33.031 2.757 3.888 3.811 10766.10 86.258 31.584 2.731 3.827 3.765 10767.10 90.565 33.622 2.694 3.869 3.792 10768.10 90.229 33.432 2.699 3.844 3.809 10769.10 85.479 31.782 2.690 3.776 3.776 10770.10 89.645 32.244 2.780 3.852 3.764 10771.40 89.171 32.788 2.720 3.874 3.794 10772.10 85.023 32.001 2.657 3.854 3.804 10773.10 84.776 31.602 2.683 3.824 3.757 10774.20 90.153 33.513 2.690 3.861 3.809 10775.10 86.228 31.746 2.716 3.839 3.770 10776.10 88.927 32.932 2.700 3.884 3.788 10777.20 85.846 32.082 2.676 3.819 3.802 10778.10 81.660 30.791 2.652 3.800 3.758 10779.10 92.451 32.331 2.860 3.851 3.804 10780.40 87.281 30.326 2.878 3.799 3.759 10781.70 85.354 31.248 2.732 3.874 3.784 10782.10 87.212 31.187 2. 796 3. 868 3. 804 10786.20 86.330 32.506 2.656 3.844 3.792 10787.10 85.733 31.061 2.760 3.889 3.806 10788.10 82.509 30.758 2.683 3.853 3.806 10789.50 91.811 32.671 2.810 3.889 3.792 Sample Area, cm2 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 .074 .335 .139 .329 .407 .133 .293 .395 .198 .127 .305 .365 .086 .395 .163 .270 .353 .092 .365 .098 .246 .365 .293 .377 .377 .293 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Dry Grain Depth, Weight, Volume, feet 9m cc 5 179A 10790.20 89.495 32.563 5 180A 10791.10 82.545 31.230 5 181A 10792.10 84.400 30.618 5 182A 10793.30 83.711 30.650 5 183A 10794.10 85.288 31.512 5 184A 10795.10 82.225 30.140 5 185A 10796.30 80.979 29.819 5 186A 10797.10 85.175 30.639 5 187A 10798.10 81.238 29.928 5 188A 10799.35 81.222 29.821 5 189A 10800.10 84.424 30.834 5 190A 10801.10 83.728 30.612 5 191A 10802.20 85.099 31.633 5 192A 10803.10 84.036 31.478 5 193A 10804.60 99.171 37.129 5 194A 10805.70 94.908 35.781 5 195A 10806.10 89.382 33.726 5 196A 10807.10 80.043 30.244 5 203A 10815.25 . 82.817 30.667 5 204A 10816.70 82.540 30.828 5 205A 10817.70 95.468 33.803 5 209A 10821.70 91.028 33.051 Grain Density, 9m/cc 2.748 2.643 2.757 2.731 2.707 2.728 2.716 2.780 2.714 2.724 2.738 2.735 2.690 2.670 2.671 2.652 2.650 2.647 2.701 2.677 2.824 2.754 Sample Length, cm Sample Diameter, cm Sample Area, om2 3.893 3.879 3.855 3.866 3.815 3.841 3.821 3.816 3.821 3.904 3.872 3.868 3.808 3.836 3.807 3.830 3.838 3.855 3.875 3.837 3.794 3.800 3.790 3.775 3.785 3.790 3.785 3.780 3.780 3.779 3.788 3.771 3.823 3.797 3.794 3.807 3.791 3.804 3.808 3.845 11.305 11.341 11.282 11.192 11.252 11.282 11.252 11.222 11.222 11.216 11.270 11.169 11.479 11.323 11.305 11.383 11.287 11.365 11.389 11.611 + Sample Unsuitable for CMS Measurement +++ Sample failed in CMS, not recoverable Core Laboratories ]' British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet I 1V I 2V I 3V I 4V 1 5V I 6V I 7V I 8V I 9V I 10V 1 11'V 1 12V 1 13V 1 14V 1 15V I 16V I 17V 1 18V I 19V 2 20V 2 21V 2 22V 10523.30 10524.30 10525.30 10526.30 10527.30 1O528.30 10529.30 10530.3O 10531.20 10532.30 10533.20 10534.20 10535.30 10536.20 1O537.3O 10538.20 10539.20 10540.30 10541.20 10624.00 10625.00 10626.00 Dry Weight, 9m 107.230 111.037 113.927 99.747 94.328 92.029 94.143 96.857 93.392 93.489 92.683 94.158 93.754 97.018 97.010 93.525 98.781 98.659 99.857 126.601 123.407 79.790 Grain Volume, CC 40.221 38.646 38.260 35.422 35.103 34.192 35.123 35.893 34.923 34.736 34.473 35.123 34.984 36.009 35.731 34.793 36.541 35.777 36.460 44.675 45.503 28.947 Grain Density, gm/cc 2.666 2.873 2.978 2.816 2.687 2.692 2.680 2.698 2.674 2.691 2.689 2.681 2.680 2.694 2.715 2.688 2.703 2.758 2.739 2.834 2.712 2.756 Sample Length, cm Sample Diameter, cm Sample Area, cm2 3.640 3.807 3.829 3.820 3.857 3.871 3.899 3,641 3.796 3.850 3.765 3.856 3.844 3.858 3,898 3.837 3.861 3.861 3.838 4.831 5.110 3.251 3.772 3.798 3.790 3.793 3.758 3.755 3.753 3.801 3.798 3,773 3.798 3.798 3.784 3.800 3.759 3.752 3.798 3.758 3.797 3.802 3.781 3.784 11.175 11.329 11.282 11.299 11.092 11.074 11.062 11.347 11,329 11.181 11.329 11.329 11.246 11.341 11.098 11.056 11.329 11.092 11.323 11.353 11.228 11.246 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet 2 23V 2 25V 2 26V 2 27V 2 28V 2 29V 2 30V 2 31V 2 32V 2 33V 2 34V 2 35V 2 36V 2 37V 2 38V 2 39V 2 41V 2 42V 2 43V 2 44V 2 45V 2 46V 2 47V 2 48V 2 49V 2 50V 10627.00 10629.00 10630.50 10631.00 10632.00 10633.20 10634.20 10635.00 10636.00 10637.00 10638.00 10639.00 10640.50 10641.30 10642.00 10643.20 10645.00 10646.20 10647.00 10648.00 10649.20 10650.00 10651.00 10651.85 10653.00 10654.00 Dry Weight, ~lm 124.762 116.821 114.387 110.676 125.874 110.2O2 108.381 112.828 108.523 95.556 117.752 111.704 106.743 101.203 124.652 119.339 127.290 114.160 114.437 128.887 117.906 124.102 112.197 69.812 119.565 112.734 Grain Volume, cc 45.152 44.155 42.550 41.780 44.022 41.621 39.982 42.813 41.109 36.278 44.561 42.396 40.321 38.388 46.488 44.952 46.820 43.073 43.260 47.891 43.925 45.264 42.372 26.286 43.620 42.533 Grain Density, gm/cc 2.763 2.646 2.688 2.649 2.859 2.648 2.711 2.635 2.640 2.634 2.642 2.635 2.647 2.636 2.681 2.655 2.719 2.650 2.645 2.691 2.684 2.742 2.648 2.656 2.741 2.651 Sample Length, cm Sample Diameter, cm Sample Area, cm2 5.042 5.008 5.011 5.063 5.065 4.989 4.539 5.064 5.094 4.294 5.062 4.976 4.982 4.391 5.156 5.085 5.121 4.994 5.001 5.012 5.030 5.022 5.150 3.403 4.998 5.013 3.785 3.799 3.796 3.790 3.797 3.795 3.796 3.800 3.772 3.770 3.794 3.765 3.787 3.786 3.801 3.801 3.787 3.787 3.787 3.788 3.788 3.788 3.764 3.747 3.786 3.787 11.252 11.335 11.317 11.282 11.323 11.311 11.317 11.341 11.175 11.163 11.305 11.133 11.264 11.258 11.347 11.347 11.264 11.264 11.264 11.270 11.270 11.270 11.246 11.027 11.258 11.264 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet 2 51V 2 52V 2 53V 2 54V 2 55V 2 56V 3 57V 3 58V 3 59V 3 60V 3 61V 3 62V 3 63V 3 64V 3 65V 3 66V 3 67V 3 68V 3 69V 3 70V 3 71V 3 72V 3 73V 3 74V 3 75V 3 76V 10655.20 10656.00 10657.00 10658.20 10659.20 10660,00 10662.00 10663.00 10664.00 10665.10 10666.00 10667.00 10668.10 10669.00 10670.40 10671.45 10672.30 10673.00 10674.50 10675.00 10676,00 10677,20 10678.00 10679.00 10680,20 10681.00 Dry Weight, 9m 112.251 114.081 130.308 115.797 116.984 120.234 120.509 127.879 118.330 115.297 121.342 107.743 113.407 111.271 116.842 120.361 120.851 123.906 119.992 116.962 117.494 110.088 107.885 105.743 113.950 114.515 Grain Volume, CC 42.338 42.338 47.196 43,175 43.620 44.617 44,216 45.215 43.481 42.314 44,228 4O.365 42.540 41.712 43,051 44.232 44.848 45.697 44.916 43.867 41.941 40.947 40.276 39.453 43.059 42.602 Grain Density, ~lm/cc 2.651 2.695 2.761 2.682 2.682 2.695 2.725 2.828 2.721 2.725 2.744 2.669 2.666 2.668 2.714 2.721 2.695 2.711 2.671 2.666 2.801 2.689 2.679 2.680 2.646 2.688 Sample Length, cm Sample Diameter, cm Sample Area, om2 5.020 5.147 5,157 4,979 5.057 5.147 5.204 5,103 5.165 5.119 5,161 5.043 5.147 5.093 5,114 4,994 5,097 5.018 5.152 5,042 5.110 5,116 5.072 5.011 5.114 5.162 3.785 3.787 3.786 3.785 3.801 3.799 3.763 3.751 3.764 3.735 3.762 3.765 3.759 3.762 3.763 3.757 3.766 3.781 3.760 3.767 3.770 3.768 3.761 3.776 3.768 3.778 11.252 11.264 11.258 11.252 11.347 11.335 11.121 11.051 11.127 10.956 11.115 11.133 11.098 11.115 11.121 11.086 11.139 11.228 11.104 11.145 11.163 11.151 11.110 11.198 11.151 11.210 Core Laboratories British Petroleum 13-06A Well Core Number SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples I Sample Dry Sample Depth, Weight, Number feet gm 3 77V 3 78V 3 79V 3 80V 3 81V 3 82V 3 83V '3 84V 3 85V 3 87V 3 88V 3 89V 3 90V 3 91V 3 93V 3 94V 3 95V 3 96V 3 97V 3 99V 3 100V 3 101V 3 102V 3 103V 3 104V 3 106V File: DAL-97369 Grain Volume, cc Grain Density, gm/cc Sample Length, cm 10682.00 112.548 41.812 2.692 4.995 10683.20 113.187 41.995 2.695 5.155 10684.00 107.818 40.383 2.670 4.999 10685.00 113.836 41.981 2.712 5.130 10686.20 109.522 40.583 2.699 4.998 10687.00 109.074 41.045 2.657 5.060 10687.90 118.350 43.792 2.703 4.995 10689.20 133.166 47.989 2.775 5.025 10690.00 127.249 46.942 2.711 5.126 10692.00 124.244 46.068 2.697 5.078 10693.80 151.056 51.643 2.925 5.168 10695.00 145.431 52.931 2.748 5.125 10696.10 120.321 44.897 2.680 5.145 10697.00 122.029 45.674 2.672 5.065 10699.00 132.127 46.902 2.817 5.119 10700.00 123.047 45.941 2.678 5.099 10701.00 122.584 45.507 2.694 5.112 10702.10 124.642 46.113 2.703 5.061 10703.00 119.184 44.365 2.686 5.099 10705.05 101.958 37.167 2.743 4.067 10706.45 114.287 42.740 2.674 5.132 10707.00 114.849 42.546 2.699 5.048 10708.00 116.299 43.767 2.657 5.140 10709.00 119.334 43.587 2.738 5.003 10710.40 120.755 44.992 2.684 5.145 10712.00 125.993 45.383 2.776 5.146 Sample Diameter, Gm Sample Area, Gm2 3.767 3.776 3.773 3.774 3.765 3.773 3.782 3.772 3.768 3.771 3.784 3.769 3.773 3.769 3.774 3.782 3.773 3.777 3.770 3.780 3.767 3.782 3.781 3.784 3.777 3.770 11.145 11.198 11.181 11.186 11.133 11.181 11.234 11.175 11.151 11.169 11.246 11.157 11.181 11.157 11.186 11.234 11.181 11.204 11.163 11.222 11.145 11.234 11.228 11.246 11.204 11.163 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet 3 107V 3 108V 3 109V 3 110V 3 111V 3 112V 3 113V 3 114V 4 115V 4 116V 4 117V 4 118V 4 119V 4 120V 4 121V 4 122V 4 123V 4 124V 4 125V 4 127V 4 129V 4 130V 4 131V 4 132V 4 133V 4 134V 10713.00 10714.00 10715.00 10716.00 10717.30 10718.00 1O72O.2O 10722.30 10724.00 10725.00 10726.00 10727.00 10728.10 10729.00 10730.00 10731.05 10732.35 10733.00 10735.00 10736.00 10736.80 10738.15 10739.00 10740.20 10741.10 10742.00 Dry Weight, ~m 118.065 92.311 121.889 115.311 120.787 114.000 115.703 117.035 116.484 119.127 123.383 121.787 119.246 118.773 131.216 86.801 131.190 135.280 138.626 111.658 125.995 148.774 126.952 Grain Volume, CC 43.130 32.579 43.9O7 42.839 44.838 42.562 43.410 42.961 43.619 44.133 45.594 45.889 44.491 44.420 46.087 32.739 48.681 49.704 50.698 39.245 47.706 53.038 47.005 Grain Density, ~m/cc 2.737 2.833 2.776 2.692 2.694 2.678 2.665 2.724 2.670 2.699 2.706 2.654 2.680 2.674 2.847 2.651 2.695 2,722 2.734 2.845 2.641 2.805 2.701 #DIV/0! #DIV/0! #DIV/0I Sample Length, cm Sample Diameter, cm Sample Area, cm2 5.034 3.625 5.102 4.989 5.095 5.077 5.099 5.064 5.050 5.078 5.018 5.019 5.033 5.099 5.081 3.491 5.134 5.159 5.159 3.660 5.098 5.153 5.013 3.771 3.774 3.785 3.771 3.773 3.771 3.771 3.784 3.782 3.754 3.785 3.772 3.784 3.775 3.775 3.773 3.782 3.786 3.786 3.798 3.784 3.784 3.792 11.169 11.186 11.252 11.169 11.181 11.169 11.169 11.246 11.234 11.068 11.252 11.175 11.246 11.192 11.192 11.181 11.234 11.258 11.258 11.329 11.246 11.246 11.293 0.000 0.000 0.000 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet 4 135V 4 136V 4 137V 4 138V 4 139V 4 140V 4 141V 4 142V 4 144V 4 145V 4 147V 4 148V 4 150V 4 151V 4 152V 4 153V 4 154V 4 155V 4 156V 4 157V 4 158V 4 159V 4 160V 4 161V 4 162V 4 163V Dry Grain Weight, Volume, ~lm cc Grain Density, gm/cc Sample Length, cm Sample Diameter, cm Sample Area, cm2 10743.20 104.449 35.862 2.913 3.875 3.779 11.216 10744.00 123.771 44.323 2.793 5.135 3.770 11.163 10745.00 88.720 31.973 2.775 3.750 3.782 11.234 10746.30 115.779 42.172 2.745 4.952 3.787 11.264 10747.00 126.620 44.756 2.829 5.139 3.784 11.246 10748.35 #DIV/0! 0.000 10749.30 119.369 43.470 2.746 4.877 3.772 11.175 10750.00 86.463 31.304 2.762 3.793 3.782 11.234 10752.00 119.186 43.426 2.745 4.868 3.787 11.264 10753.00 119.040 44.060 2.702 5.129 3.783 11.240 10755.70 79.944 29.541 2.706 3.389 3.787 11.264 10756.50 89.584 33.255 2.694 3.877 3.781 11.228 10758.30 118.360 43.335 2.731 5.172 3.778 11.210 10759.10 121.734 44.067 2.762 5.185 3.785 11.252 10760.00 118.034 43.381 2.721 5.066 3.790 11.282 10761.00 123.169 45.575 2.703 5.119 3.790 11.282 10762.00 130.611 47.636 2.742 5.082 3.794 11.305 10763.00 151.997 51.232 2.967 5.205 3.790 11.282 10764.00 121.710 44.320 2.746 5.136 3.791 11.287 10765.30 118.134 42.973 2.749 5.047 3.786 11.258 10766.00 119.190 43.483 2.741 5.129 3.789 11.276 10767.00 82.168 30.864 2.662 3.749 3.773 11.181 10768.00 117.948 43.016 2.742 5.099 3.782 11.234 10769.00 91.443 33.474 2.732 3.873 3.781 11.228 10770.00 126.114 44.457 2.837 5.096 3.787 11.264 10771.30 112.797 41.748 2.702 5.046 3.786 11.258 Core Laboratories British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet 4 164V 4 165V 4 166V 4 167V 4 168V 4 169V 4 170V 4 171V 4 172V 4 173V 4 174V 5 175V 5 176V 5 177V 5 179V 5 180V 5 181V 5 182V 5 183V 5 184V 5 185V 5 186V 5 187V 5 188V 5 189V 5 190V 10772.00 10773.00 10774.10 10775.00 10776.00 10777.10 1O778.00 10779.00 10780.30 10781.60 10782.00 10786.10 1O787.00 1O788.00 10790.10 10791.00 10792.00 10793.30 10794. O0 10795.00 1O796.20 10797.00 10798.00 10799.25 1080O.00 10801.00 Dry Weight, 111.754 119.043 117.053 117.854 115.928 114.981 81.537 111.981 116.588 116.903 119.862 115.236 112.246 111.560 112.999 105.328 67.416 112.336 113.199 108.447 110.137 112.791 73.845 109.948 112.235 113.528 Grain Volume, 42.226 44.270 43.381 43.805 42.827 43.071 30.656 42.234 41.479 41.672 42.268 42.398 39.721 41.474 41.497 40.006 24.717 41.396 42.063 40.263 40.460 41.163 27.324 40.359 41.182 41.695 Grain Density, gm/cc 2.647 2.689 2.698 2.690 2.707 2.67O 2.660 2.651 2.811 2.805 2.836 2.718 2.826 2.690 2.723 2.633 2.727 2.714 2,691 2.693 2.722 2.740 2.703 2.724 2.725 2.723 Sample Length, om Sample Diameter, cm Sample Area, cmz 5.114 5.092 5.073 5.151 5.113 5.075 3.825 5.084 5.074 5.107 5.129 5.120 4.889 5.203 5.135 5.135 3.255 5.180 5.131 5.146 5.152 5.221 3.553 5.159 5.205 5.144 3.772 3.789 3.772 3.793 3.788 3.797 3.774 3.792 3.790 3.797 3.786 3.787 3.782 3.779 3.777 3.773 3.773 3.772 3.778 3.766 3.790 3.779 3.744 3.765 3.788 3.773 11.175 11.276 11.175 11.299 11.270 11.323 11.186 11.293 11.282 11.323 11.258 11.264 11.234 11.216 11.204 11.181 11.181 11.175 11.210 11.139 11.282 11.216 11.009 11.133 11.270 11.181 Core Laboratories r' British Petroleum 13-06A Well SUMMARY OF GRAIN DENSITY MEASUREMENTS Dean Stark Samples File: DAL-97369 Core Number Sample Number Sample Depth, feet Dry Weight, ~lm 5 191V 10802.10 110.489 5 192V 10803.00 111.698 5 194V 10805.60 85.079 5 195V 10806.00 117.847 5 196V 10807.00 106.288 5 204V 10822.60 79.205 Grain Volume, 41.668 42.212 32.164 44.338 40.136 29.373 Grain Density, ~lm/cc 2.652 2.646 2.645 2.658 2.648 2.697 Sample Length, cm Sample Diameter, cm Sample Area, cm2 5.068 5.157 3.655 5.180 5.258 3.660 3.791 3.786 3.794 3.789 3.776 3.775 11.287 11.258 11.305 11.276 11.198 11.192 + Sample Unsuitable for CMS Measurement +++ Sample failed in CMS, not recoverable Core Laboratories Facility Date/Time 08 Dec 97 09 Dec 97 10 Dec 97 11 Dec 97 12 Dec 97 13 Dec 97 14 Dec 97 Progress Report PB DS 13 Well 13-06A Rig Doyon 141 Page 1 Date 11 February 98 04:00-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-01:30 01:30-03:30 03:30-06:00 06:00-09:00 09:00-14:30 14:30-19:00 19:00-20:00 20:00-22:00 22:00-01:30 01:30-02:00 02:00-03:00 03:00-06:00 06:00-07:00 07:00-08:00 08:00-10:00 10:00-12:00 12:00-12:30 12:30-14:30 14:30-16:30 16:30-18:30 18:30-19:30 19:30-03:30 03:30-06:00 06:00-08:30 08:30-09:00 09:00-12:00 12:00-12:30 12:30-13:30 13:30-20:00 20:00-00:00 00:00-00:30 00:30-02:00 02:00-03:30 03:30-04:00 04:00-06:00 06:00-08:00 08:00-09:30 09:30-20:30 20:30-22:00 22:00-00:00 00:00-00:30 00:30-01:00 01:00-04:00 04:00-06:00 Duration 2 hr 6 hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 11-1/2 hr 1/2 hr 1 hr 2 hr 2-1/2 hr 3 hr 5-1/2 hr 4-1/2 hr 1 hr 2 hr 3-1/2 hr 1/2 hr 1 hr 3 hr 1 hr 1 hr 2 hr 2 hr 1/2 hr 2 hr 2 hr 2 hr 1 hr 8 hr 2-1/2 hr 2-1/2 hr 1/2 hr 3 hr 1/2 hr 1 hr 6-1/2 hr 4 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 2 hr 2 hr 1-1/2 hr 11 hr 1-1/2 hr 2 hr 1/2 hr 1/2 hr 3 hr 2 hr Activity Rigged down Additional services Rigged down Additional services (cont...) Held safety meeting Rig moved 100.00 % Held safety meeting Rigged up Additional services Rigged up Additional services (cont...) Held safety meeting Rigged up Additional services Held safety meeting Tested Hanger plug Rigged down Xmas tree Rigged up BOP stack Rigged up BOP stack Tested BOP stack Tested Blind ram Retrieved Hanger plug Installed Tubing retrieval string Circulated at 10200.0 ft Laid down 93.0 ft of Tubing Rigged down Drillfloor / Derrick Laid down 1800.0 ft of Tubing Laid down 120.0 ft of Tubing Installed Other sub-surface equipment Removed BOP stack Serviced Tubing head spool Held safety meeting Serviced Tubing head spool Installed BOP stack Tested BOP stack Retrieved Other sub-surface equipment Laid down 8026.0 ft of Tubing Set downhole equipment (wireline) Set downhole equipment (wireline) Tested Casing Tested Top ram Held safety meeting Installed Wear bushing Made up BHA no. 1 Singled in drill pipe to 4100.0 ft Held safety meeting Rigged up Kelly Singled in drill pipe to 5853.0 ft Serviced Draw works Singled in drill pipe to 6944.0 ft Took MWD survey at 6944.0 ft N Circulated at 6958.0 ft ~Milled Casing at 6958.0 fl Circulated at 6998.0 ft Pulled out of hole to 6998.0 ft Held safety meeting Pulled out of hole to 906.0 ft Pulled BHA Made up BHA no. 2 Anchorage Facility Date/Time 15 Dec 97 16 Dec 97 17 Dec 97 18 Dec 97 19 Dec 97 20 Dec 97 21 Dec 97 PB DS 13 Progress Report Well 13-06A Rig Doyon 141 Page Date 06:00-07:30 07:30-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-06:00 06:00-11:00 11:00-12:00 12:00-13:00 13:00-13:30 13:30-16:00 16:00-17:00 17:00-06:00 06:00-11:00 11:00-13:00 13:00-22:30 22:30-23:30 23:30-00:30 00:30-01:30 01:30-06:00 06:00-09:00 09:00-10:30 10:30-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-18:30 18:30-20:00 20:00-23:30 23:30-06:00 06:00-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-14:30 14:30-16:30 16:30-18:00 18:00-06:00 06:00-08:00 08:00-11:00 11:00-12:45 12:45-13:00 13:00-15:30 15:30-17:00 17:00-17:30 17:30-21:30 21:30-00:00 00:00-00:15 00:15-01:00 01:00-02:00 02:00-04:30 04:30-06:00 06:00-06:30 06:30-07:30 Duration 1-1/2 hr 3 hr 1/2 hr 1 hr 1/2 hr 17-1/2 hr 5 hr 1 hr 1 hr 1/2 hr 2-1/2 hr 1 hr 13hr 5 hr 2 hr 9-1/2 hr 1 hr 1 hr 1 hr 4-1/2 hr 3 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1 hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 3-1/2 hr 6-1/2 hr 24 hr 3 hr 3 hr 1/2 hr 2 hr 2 hr 1-1/2 hr 12 hr 2 hr 3 hr 1-3/4 hr 1/4 hr 2-1/2 hr 1-1/2 hr 1/2 hr 4 hr 2-1/2 hr 1/4 hr 3/4 hr 1 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1 hr Activity Made up BHA no. 2 R.I.H. to 6926.0 ft Set tool face Reamed to 6998.0 ft Held safety meeting Drilled to 7840.0 ft Drilled to 8000.0 ft Circulated at 8000.0 ft Pulled out of hole to 6928.0 ft R.I.H. to 8000.0 ft Drilled to 8094.0 ft Investigated pressure change Drilled to 8560.0 ft Drilled to 8726.0 ft Serviced Washpipe Drilled to 9004.0 ft Circulated at 9004.0 ft Pulled out of hole to 8546.0 ft R.I.H. to 9004.0 ft Drilled to 9120.0 ft Drilled to 9191.0 ft Circulated at 9191.0 ft Pulled out of hole to 5800.0 ft Held safety meeting Pulled out of hole to 1103.0 ft Pulled BHA Tested BOP stack Made up BHA no. 3 R.I.H. to 9191.0 ft Drilled to 9540.0 ft Drilled to 10383.0 ft Drilled to 10404.0 ft Drilled to 10620.0 ft Held safety meeting Drilled to 10620.0 ft Circulated at 10620.0 ft Pulled out of hole to 6920.0 ft Serviced Fluid system R.I.H. to 10614.0 ft Circulated at 10620.0 ft Pulled out of hole to 9920.0 ft R.I.H. to 10449.0 ft Reamed to 10620.0 ft Circulated at 10620.0 ft Drilled to 10628.0 ft Circulated at 10620.0 ft Pulled out of hole to 6144.0 ft Held safety meeting Laid down 810.0 ft of 5in OD drill pipe Serviced Block line Pulled out of hole to 1110.0 ft Pulled BHA Pulled BHA Made up BHA no. 4 2 11 February 98 Facility Date/Time 22 Dec 97 23 Dec 97 24 Dec 97 PB DS 13 Progress Report Well 13-06A Rig Doyon 141 Page Date 07:30-10:00 10:00-11:30 11:30-13:30 13:30-15:00 15:00-17:00 17:00-19:00 19:00-21:00 21:00-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-14:30 14:30-19:00 19:00-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-10:00 10:00-11:15 11:15-12:45 12:45-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-21:00 21:00-21:15 21:15-22:00 22:00-22:15 22:15-23:30 23:30-23:45 23:45-00:15 00:15-00:45 00:45-02:30 02:30-03:00 03:00-03:30 03:30-04:45 04:45-06:00 06:00-08:30 08:30-14:00 14:00-15:30 15:30-16:30 16:30-17:30 17:30-19:30 19:30-20:30 20:30-21:30 Duration 2-1/2 hr 1-1/2 hr 2 hr 1-1/2 hr 2 hr 2 hr 2 hr 9 hr 1-1/2 hr 1 hr 1/2 hr 5-1/2 hr 4-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 2 hr 1/2 hr 1-1/2 hr 1 hr 1 hr 1 hr 1 hr 1-1/4 hr 1-1/2 hr 1-1/4 hr 1 hr 3 hr 1/2 hr 1 hr 1/2 hr 1 hr 1/4 hr 3/4 hr 1/4 hr 1-1/4 hr 1/4 hr 1/2 hr 1/2 hr 1-3/4 hr 1/2 hr 1/2 hr 1-1/4 hr 1-1/4 hr 2-1/2 hr 5-1/2 hr 1-1/2 hr 1 hr 1 hr 2hr 1 hr 1 hr Activity R.I.H. to 6900.0 ft Circulated at 6900.0 ft R.I.H. to 9613.0 ft Reamed to 9890.0 ft Circulated at 9890.0 ft Reamed to 10120.0 ft Reamed to 10095.0 ft Reamed to 10435.0 ft Reamed to 10468.0 ft Pulled out of hole to 9787.0 ft Circulated at 9787.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 9700.0 ft Circulated at 9700.0 ft Circulated at 9700.0 ft Held safety meeting Pulled out of hole to 8948.0 ft Circulated at 8948.0 ft Monitor pressures Circulated at 8950.0 ft Pulled out of hole to 6940.0 ft Circulated at 6940.0 ft Monitor pressures Circulated at 6940.0 ft Bullhead well Circulated at 6940.0 ft Monitor pressures Circulated at 6940.0 ft Monitor pressures Circulated at 6940.0 ft Ran Drillpipe in stands to 7542.0 ft Circulated at 7542.0 ft Ran Drillpipe in stands to 8010.0 ft Circulated at 8010.0 ft Ran Drillpipe in stands to 8477.0 ft Circulated at 8477.0 ft Ran Drillpipe in stands to 8948.0 ft Circulated at 8948.0 ft Pumped Water spacers - volume 20.000 bbl Batch mixed slurry - 49.000 bbl Pulled out of hole to 8605.0 ft Circulated at 8605.0 ft Batch mixed slurry - 35.000 bbl Pumped out of hole to 8350.0 ft Circulated at 8350.0 ft Pulled out of hole to 7265.0 ft Pulled out of hole to 0.0 ft Tested BOP stack Made up BHA no. 5 R.I.H. to 1100.0 ft Serviced Block line R.I.H. to 6990.0 ft Circulated at 6990.0 ft R.I.H. to 8103.0 ft 3 11 February 98 Facility Date/Time 25 Dec 97 26 Dec 97 27 Dec 97 28 Dec 97 29 Dec 97 30 Dec 97 PB DS 13 Progress Report Well 13-06A Rig Doyon 141 Page Date Duration Activity 21:30-22:00 22:00-00:30 00:30-03:00 03:00-06:00 06:00-06:30 06:30-07:30 07:30-11:00 11:00-13:00 13:00-16:00 16:00-17:00 17:00-19:30 19:30-20:00 20:00-06:00 06:00-18:00 18:00-21:00 21:00-22:30 22:30-00:00 00:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-18:00 18:00-19:00 19:00-20:00 20:00-06:00 06:00-13:30 13:30-14:30 14:30-19:00 19:00-20:00 20:00-21:00 21:00-23:00 23:00-00:30 00:30-01:30 01:30-02:00 02:00-06:00 06:00-15:00 15:00-16:00 16:00-17:30 17:30-23:00 23:00-00:00 00:00-00:30 00:30-00:45 00:45-06:00 06:00-08:00 08:00-08:30 08:30-09:30 09:30-11:30 11:30-12:00 12:00-13:30 13:30-15:30 15:30-20:00 20:00-22:00 22:00-23:00 23:00-02:30 1/2 hr 2-1/2 hr 2-1/2 hr 3 hr 1/2 hr 1 hr 3-1/2 hr 2 hr 3 hr 1 hr 2-1/2 hr 1/2 hr 10hr 12hr 3 hr 1-1/2 hr 1-1/2 hr 3 hr 1 hr 1 hr 1 hr 12 hr 1 hr 1 hr 10hr 7-1/2 hr 1 hr 4-1/2 hr 1 hr 1 hr 2 hr 1-1/2 hr 1 hr 1/2 hr 4 hr 9 hr 1 hr 1-1/2 hr 5-1/2 hr 1 hr 1/2 hr 1/4 hr 5-1/4 hr 2 hr 1/2 hr 1 hr 2 hr 1/2 hr 1-1/2 hr 2 hr 4-1/2 hr 2 hr 1 hr 3-1/2 hr Washed to 8347.0 ft Drilled cement to 8506.0 ft Drilled to 8516.0 ft Circulated at 8516.0 ft Drilled to 8518.0 ft Serviced Mud shakers Drilled to 8564.0 ft Circulated at 8564.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 8564.0 ft Set tool face Drilled to 8755.0 ft Drilled to 9101.0 ft Circulated at 9101.0 ft Flow check Circulated at 9101.0 ft Circulated at 9101.0 ft Flow check Circulated at 9101.0 ft Drilled to 9133.0 ft Drilled to 9507.0 ft Circulated at 9507.0 ft Pulled out of hole to 8450.0 ft Drilled to 9851.0 ft Drilled to 10099.0 ft Circulated at 10.1 ft Pulled out of hole to 1100.0 ft Made up BHA no. 7 R.I.H. to 1100.0 ft R.I.H. to 6898.0 ft Serviced Block line R.I.H. to 10050.0 ft Washed to 10099.0 ft Drilled to 10235.0 ft Drilled to 10510.0 ft Circulated at 10510.0 ft Pulled out of hole to 6960.0 ft Serviced Trip tank R.I.H. to 9522.0 ft R.I.H. to 10487.0 ft Washed to 10510.0 ft Circulated at 10510.0 ft Circulated at 10510.0 ft Drilled to 10520.0 ft Circulated at 10520.0 ft Pulled out of hole to 6898.0 ft Circulated at 6898.0 ft R.I.H. to 10520.0 ft Circulated at 10520.0 ft Pulled out of hole to 1100.0 ft Pulled BHA Serviced Rotary table Made up BHA no. 8 4 11 February 98 Facility Date/Time 31 Dec 97 01 Jan 98 02 Jan 98 03 Jan 98 04 Jan 98 PB DS 13 Progress Report Well 13-06A Rig Doyon 141 Page Date Duration Activity 02:30-06:00 06:00-08:00 08:00-12:00 12:00-14:00 14:00-14:30 14:30-18:00 18:00-23:00 23:00-02:00 02:00-03:30 03:30-04:30 04:30-06:00 06:00-09:00 09:00-11:00 11:00-14:30 14:30-15:30 15:30-16:30 16:30-19:00 19:00-22:30 22:30-22:45 22:45-00:30 00:30-02:30 02:30-03:30 03:30-06:00 06:00-08:00 08:00-10:00 10:00-12:00 12:00-14:00 14:00-16:00 16:00-19:00 19:00-02:30 02:30-03:00 03:00-04:30 04:30-06:00 06:00-08:00 08:00-11:30 11:30-13:00 13:00-14:00 14:00-15:00 15:00-16:00 16:00-16:30 16:30-19:30 19:30-20:00 20:00-21:00 21:00-00:00 00:00-01:00 01:00-01:30 01:30-02:00 02:00-04:00 04:00-06:00 06:00-08:00 08:00-09:30 09:30-10:00 10:00-12:00 12:00-12:30 3-1/2 hr 2 hr 4 hr 2 hr 1/2 hr 3-1/2 hr 5 hr 3 hr 1-1/2 hr 1 hr 1-1/2 hr 3 hr 2 hr 3-1/2 hr 1 hr 1 hr 2-1/2 hr 3-1/2 hr 1/4 hr 1-3/4 hr 2 hr 1 hr 2-1/2 hr 2 hr 2 hr 2 hr 2 hr 2 hr 3 hr 7-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 2 hr 3-1/2 hr 1-1/2 hr 1 hr 1 hr 1 hr 1/2 hr 3 hr 1/2 hr 1 hr 3 hr 1 hr 1/2 hr 1/2 hr 2 hr 2 hr 2 hr 1-1/2 hr 1/2 hr 2 hr 1/2 hr R.I.H. to 10460.0 ft Reamed to 10520.0 ft Cored to 10542.0 ft Circulated at 10540.0 ft Pulled out of hole to 9577.0 ft Circulated at 9577.0 ft Pulled out of hole to 1200.0 ft Pulled BHA Laid out Aluminium sleeve core Serviced Rotary table Tested Annular preventor Tested BOP stack Made up BHA no. 9 R.I.H. to 6958.0 ft Serviced Block line Circulated at 6958.0 ft R.I.H. to 10525.0 ft Reamed to 10542.0 ft Circulated at 10542.0 ft Circulated at 10525.0 ft Pulled out of hole to 6958.0 ft Flow check Circulated at 10542.0 ft Circulated at 6894.0 ft Flow check Circulated at 6894.0 ft Flow check R.I.H. to 10455.0 ft Reamed to 10455.0 ft Drilled to 10598.0 ft Circulated at 10585.0 ft Pulled out of hole to 6894.0 ft Flow check Flow check Circulated at 6894.0 ft R.I.H. to 10548.0 ft Reamed to 10598.0 ft Circulated at 10598.0 ft Drilled to 10606.0 ft Pumped out of hole to 10110.0 ft Circulated at 10110.0 ft R.I.H. to 10596.0 ft Reamed to 10606.0 ft Circulated at 10606.0 ft Drilled to 10609.0 ft Circulated at 10609.0 ft Drilled to 10610.0 ft Circulated at 10610.0 ft Pulled out of hole to 6894.0 ft Pulled out of hole to 735.0 ft Pulled BHA Made up BHA no. 10 R.I.H. to 9868.0 ft Circulated at 9868.0 ft 5 11 February 98 Facility Date/Time 05 Jan 98 06 Jan 98 07 Jan 98 08 Jan 98 PB DS 13 Progress Report Well 13-06A Rig Doyon 141 Duration Activity 12:30-13:00 13:00-17:00 17:00-18:30 18:30-21:30 21:30-23:30 23:30-01:00 01:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-12:30 12:30-15:00 15:00-17:00 17:00-18:30 18:30-20:00 20:00-21:00 21:00-22:00 22:00-02:30 02:30-03:30 03:30-06:00 06:00-06:30 06:30-08:30 08:30-10:00 10:00-11:00 11:00-16:00 16:00-18:00 18:00-20:00 20:00-21:00 21:00-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-08:30 08:30-09:00 09:00-11:30 11:30-16:00 16:00-17:30 17:30-19:00 19:00-20:00 20:00-20:30 20:30-00:00 00:00-00:30 00:30-03:00 03:00-05:00 05:00-06:00 06:00-07:30 07:30-08:00 08:00-10:00 10:00-14:30 14:30-17:00 17:00-18:00 18:00-19:00 1/2 hr 4 hr 1-1/2 hr 3 hr 2 hr 1-1/2 hr 2-1/2 hr 1 hr 1-1/2 hr 1/2 hr 2 hr 1 hr 3 hr 2-1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 4-1/2 hr 1 hr 2-1/2 hr 1/2 hr 2 hr 1-1/2 hr 1 hr 5 hr 2 hr 2 hr 1 hr 5 hr 1 hr 2 hr 1 hr 2-1/2 hr 1/2 hr 2-1/2 hr 4-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 2 hr 1 hr 1-1/2 hr 1/2 hr 2 hr 4-1/2 hr 2-1/2 hr 1 hr 1 hr R.I.H. to 10520.0 ft Reamed to 10610.0 ft Drilled to 10624.0 ft Circulated at 10624.0 ft Pulled out of hole to 6895.0 ft Circulated at 6895.0 ft Pulled out of hole to 735.0 ft Pulled BHA Made up BHA no. 11 Made up BHA no. 11 R.I.H. to 6958.0 ft Serviced Block line Circulated at 6958.0 ft R.I.H. to 10500.0 ft Reamed to 10624.0 ft Cored to 10662.0 ft Circulated at 10600.0 ft Pulled out of hole to 8900.0 ft Circulated at 8900.0 ft Pulled out of hole to 989.0 ft Pulled BHA Laid out Aluminium sleeve core Made up BHA no. 11 R.I.H. to 6898.0 ft Circulated at 6898.0 ft R.I.H. to 10562.0 ft Reamed to 10662.0 ft Cored to 10724.0 ft Circulated at 10650.0 ft Pulled out of hole to 9700.0 ft Pulled out of hole to 988.0 ft Pulled BHA Laid out Aluminium sleeve core Made up BHA no. 12 R.I.H. to 6800.0 ft Circulated at 6800.0 ft R.I.H. to 10613.0 ft Reamed to 10613.0 ft Cored to 10786.0 ft Circulated at 10786.0 ft Pulled out of hole to 9676.0 ft Circulated at 9679.0 ft Pulled out of hole to 988.0 ft Held safety meeting Pulled BHA Made up BHA no. 13 R.I.H. to 3000.0 ft R.I.H. to 6800.0 ft Circulated at 6800.0 ft R.I.H. to 10663.0 ft Reamed to 10786.0 ft Cored to 10846.0 ft Circulated at 10846.0 ft Pulled out of hole to 9854.0 ft Page Date 6 11 February 98 Facility PB DS 13 Progress Report Well 13-06A Rig Doyon 141 Page Date 7 11 February 98 Date/Time 09 Jan 98 10 Jan 98 11 Jan 98 12 Jan 98 13 Jan 98 19:00-19:30 19:30-00:00 00:00-00:30 00:30-01:30 01:30-05:30 05:30-06:00 06:00-06:30 06:30-09:30 09:30-10:00 10:00-12:00 12:00-12:30 12:30-15:30 15:30-16:30 16:30-17:00 17:00-19:00 19:00-20:00 20:00-06:00 06:00-12:00 12:00-12:30 12:30-14:30 14:30-15:15 15:15-16:00 16:00-18:30 18:30-21:00 21:00-00:00 00:00-00:15 00:15-02:30 02:30-03:00 03:00-06:00 06:00-07:00 07:00-09:00 09:00-10:30 10:30-11:30 11:30-12:00 12:00-12:15 12:15-13:30 13:30-16:00 16:00-17:00 17:00-17:30 17:30-01:30 01:30-06:00 06:00-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-15:30 15:30-16:30 16:30-17:00 17:00-20:00 20:00-05:00 06:00-09:00 09:00-14:00 14:00-17:00 17:00-20:00 Duration 1/2 hr 4-1/2 hr 1/2 hr 1 hr 4 hr 1/2 hr 1/2 hr 3 hr 1/2 hr 2 hr 1/2 hr 3 hr 1 hr 1/2 hr 2 hr 1 hr 10hr 6 hr 1/2 hr 2 hr 3/4 hr 3/4 hr 2-1/2 hr 2-1/2 hr 3 hr 1/4 hr 2-1/4 hr 1/2 hr 3 hr 1 hr 2 hr 1-1/2 hr 1 hr 1/2 hr 1/4 hr 1-1/4 hr 2-1/2 hr 1 hr 1/2 hr 8 hr 4-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1 hr 1/2 hr 3 hr 9 hr 3 hr 5 hr 3 hr 3 hr Activity Circulated at 9854.0 ft Pulled out of hole to 2800.0 ft Held safety meeting Pulled out of hole to 988.0 ft Pulled BHA Retrieved B ore protector Installed BOP test plug assembly Tested BOP stack Installed Bore protector Made up BHA no. 14 Held safety meeting R.I.H. to 6900.0 ft Serviced Block line Circulated at 6900.0 ft R.I.H. to 10749.0 ft Reamed to 10846.0 ft Drilled to 11018.0 ft Drilled to 11094.0 ft Held safety meeting Circulated at 11094.0 fl Pulled out of hole to 10200.0 fl Worked stuck pipe at 10200.0 ft Pulled out of hole to 6958.0 ft R.I.H. to 10290.0 ft Reamed to 10686.0 ft Held safety meeting Reamed to 10749.0 ft R.I.H. to 10908.0 ft Reamed to 11083.0 fl Reamed to 11094.0 fl Circulated at 11094.0 fl Pulled out of hole to 9565.0 ft Circulated at 9565.0 fl Pulled out of hole to 9000.0 fl Held safety meeting Pulled out of hole to 6900.0 ft Pulled out of hole to 967.0 fl Pulled BHA Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Made up BHA no. 15 Held safety meeting Made up BHA no. 15 R.I.H. to 6850.0 ft Circulated at 6850.0 ft Laid down 372.0 fl of 5in OD drill pipe R.I.H. to 10673.0 ft Worked stuck pipe at 10673.0 ft Conducted electric cable operations Pulled out of hole to 0.0 fl Made up BHA no. 16 R.I.H. to 6888.0 ft Facility PB DS 13 Progress Report Well 13-06A Page Rig Doyon 141 Date 8 11 February 98 Date/Time 14 Jan 98 15 Jan 98 16 Jan 98 17 Jan 98 20:00-21:00 21:00-21:30 21:30-23:30 23:30-00:00 00:00-00:15 00:15-02:00 02:00-02:15 02:15-05:00 05:00-06:00 06:00-09:30 09:30-10:30 10:30-13:30 13:30-14:00 14:00-16:00 16:00-20:00 20:00-21:00 21:00-22:00 22:00-23:00 23:00-23:30 23:30-02:00 02:00-06:00 06:00-07:30 07:30-09:30 09:30-09:45 09:45-10:30 10:30-12:00 12:00-12:30 12:30-16:30 16:30-17:30 17:30-23:30 23:30-00:00 00:00-00:30 00:30-02:00 02:00-02:30 02:30-06:00 06:00-06:15 06:15-09:00 09:00-09:30 09:30-10:00 10:00-11:00 11:00-14:30 14:30-18:30 18:30-19:30 19:30-23:30 23:30-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-13:00 13:00-13:30 13:30-14:00 14:00-14:30 14:30-17:15 17:15-17:30 Duration 1 hr 1/2 hr 2 hr 1/2 hr 1/4 hr 1-3/4 hr 1/4 hr 2-3/4 hr 1 hr 3-1/2 hr 1 hr 3 hr 1/2 hr 2 hr 4 hr 1 hr 1 hr 1 hr 1/2 hr 2-1/2 hr 4 hr 1-1/2 hr 2 hr 1/4 hr 3/4 hr 1-1/2 hr 1/2 hr 4 hr 1 hr 6 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/4 hr 2-3/4 hr 1/2 hr 1/2 hr 1 hr 3-1/2 hr 4 hr 1 hr 4 hr 4-1/2 hr 1 hr 1 hr 1-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-3/4 hr 1/4 hr Activity Serviced Block line Circulated at 6888.0 ft R.I.H. to 10600.0 ft Circulated at 10600.0 ft Jarred stuck pipe at 10673.0 ft Pulled out of hole to 7750.0 ft Circulated at 7750.0 ft Pulled out of hole to 1201.0 ft Pulled BHA Pulled BHA Made up BHA no. 17 R.I.H. to 6800.0 ft Circulated at 6800.0 ft R.I.H. to 10560.0 ft Reamed to 11094.0 ft Circulated at 11094.0 ft Pulled out of hole to 9670.0 ft R.I.H. to 11084.0 ft Reamed to 11094.0 ft Circulated at 11094.0 ft Pulled out of hole to 919.0 ft Pulled BHA Worked on BOP - Pipe ram Held safety meeting Installed Casing handling equipment Ran Liner to 1025.0 ft (7in OD) Held safety meeting Ran Liner to 4297.0 ft (7in OD) Installed Tubing handling equipment Ran Tubing to 4208.0 ft (3-1/2in OD) Circulated at 4297.0 ft Held safety meeting Ran Drillpipe in stands to 6850.0 ft Circulated at 6850.0 ft Ran Drillpipe in stands to 11057.0 ft Ran Drillpipe to 11069.0 ft (5in OD) Circulated at 11069.0 ft Pumped Water based mud spacers - volume 90.000 bbl Mixed and pumped slurry - 200.000 bbl Displaced slurry - 151.900 bbl Circulated at 10974.0 ft Laid down 5392.0 ft of 5in OD drill pipe Installed Tubing handling equipment Laid down 4200.0 ft of Tubing Conducted electric cable operations Tested Liner Ran Drill collar to 93.0 ft (6-1/2in OD) Ran Drill collar to 5581.0 ft (5in OD) Laid down 5581.0 ft of 5in OD drill pipe Retrieved Wear bushing Held safety meeting Installed Tubing handling equipment Ran Liner to 3713.0 ft (4-1/2in OD) Installed Tubing handling equipment Facility Date/Time 18 Jan 98 PB DS 13 Progress Report Well 13-06A Rig Doyon 141 Page Date Duration Activity 17:30-21:00 21:00-22:00 22:00-00:00 00:00-00:30 00:30-04:30 04:30-05:00 05:00-06:00 06:00-09:00 09:00-10:00 10:00-12:00 12:00-12:30 12:30-13:30 13:30-16:00 16:00-19:30 19:30-20:30 20:30-22:30 22:30-00:00 3-1/2 hr 1 hr 2 hr 1/2 hr 4 hr 1/2 hr 1 hr 3 hr 1 hr 2 hr 1/2 hr 1 hr 2-1/2 hr 3-1/2 hr 1 hr 2 hr 1-1/2 hr Ran Tubing to 8193.0 ft (5-1/2in OD) Tested Dual control line Ran Tubing to 9722.0 ft (5-1/2in OD) Held safety meeting Ran Tubing to 10399.0 ft (5-1/2in OD) Tested Tubing hanger Circulated at 10399.0 ft Circulated at 10399.0 ft Tested Accessories Removed BOP stack Held safety meeting Removed BOP stack Installed Adapter spool Installed Wellhead primary components Tested Permanent packer Tested Liner Installed Accessories 9 11 February 98 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING PBU / 13-06A 500292064201 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/17/98 DATE OF SURVEY: 011198 MWD SURVEY JOB NUMBER: AKEI80083 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10254.11 8525.56 8451.56 6 59 S 69.52 E .00 606.24S 3924.29E 3970.83 10284.86 8556.08 8482.08 6 58 S 68.67 E .35 607.57S 3927.78E 3974.49 10354.50 8625.16 8551.16 7 34 S 68.16 E .87 610.82S 3935.97E 3983.09 10449.44 8719.10 8645.10 9 3 S 72.28 E 1.69 ~ 615.42S 3948.90E 3996.57 10541.00 8809.38 8735.38 10 5 S 80.11 E 1.81 618.99S 3963.67E 4011.71 10635.83 8902.88 8828.88 9 1 S 81.34 E 1.14 10730.21 8996.08 8922.08 9 9 S 80.75 E .17 10825.40 9090.04 9016.04 9 18 S 80.93 E .15 10922.23 9185.64 9111.64 8 56 S 80.44 E .38 11017.18 9279.53 9205.53 8 8 S 78.91 E .87 621.54S 3979.21E 4027.46 623.86S 3993.95E 4042.38 626.29S 4009.02E 4057.64 628.77S 4024.16E 4072.99 631.29S 4038.04E 4087.09 11044.18 9306.27 9232.27 7 58 S 76.90 E 1.24 632.09S 4041.75E 4090.87 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4090.87 FEET AT SOUTH 81 DEG. 6 MIN. EAST AT MD = 11044 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 98.89 DEG. TIE-IN SURVEY AT 10,254.11' MD LAST SURVEY STATION AT 11,044.18' MD ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU / 13-06A 500292064201 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/17/98 DATE OF SURVEY: 011198 JOB NUMBER: AKEI80083 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10254.11 8525.56 8451.56 11044.18 9306.27 9232.27 606.24 S 3924.29 E 1728.55 632.09 S 4041.75 E 1737.91 9.36 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU / 13-06A 500292064201 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/17/98 DATE OF SURVEY: 011198 JOB NUMBER: AKEI80083 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10254.11 8525.56 8451.56 606.24 S 3924.29 E 10302.91 8574.00 8500.00 608.37 S 3929.82 E 10403.79 8674.00 8600.00 613.23 S 3942.16 E 10505.07 8774.00 8700.00 617.90 S 3957.48 E 1728.55 1728.91 .36 1729.79 .88 1731.07 1.28 10606.58 8874.00 8800.00 620.85 S 3974.67 E 10707.85 8974.00 8900.00 623.29 S 3990.43 E 10809.15 9074.00 9000.00 625.88 S 4006.43 E 10910.45 9174.00 9100.00 628.47 S 4022.36 E 11011.59 9274.00 9200.00 631.14 S 4037.27 E 1732.58 1.51 1733.85 1.26 1735.15 1.30 1736.45 1.29 1737.59 1.14 11044.18 9306.27 9232.27 632.09 S 4041.75 E 1737.91 .32 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD {FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -PAGE i SHARED SERVICES DRILLING PBU / 13-06A 500292064201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010498 MWD SURVEY JOB NUMBER: AKMW80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8490.29 7099.97 7025.97 8506.00 7111.92 7037.92 8527.54 7128.58 7054.58 8566.84 7159.34 7085.34 8596.88 7182.87 7108.87 40 58 39 59 38 38 38 22 38 31 N 40.77 E .00 717.42S 3047.64E 2976.92 N 41.08 E 6.43 709.71S 3054.32E 2984.22 N 41.55 E 6.42 699.46S 3063.33E 2994.06 N 46.04 E 7.14 681.81S 3080.25E 3012.40 N 47.46 E 2.98 669.01S 3093.86E 3027.03 8628.01 7206.95 7132.95 8660.40 7231.57 7157.57 8691.75 7255.12 7181.12 8722.84 7278.26 7204.26 8755.41 7302.26 7228.26 40 5 40 57 41 40 42 5 42 57 N 47.89 E 5.15 655.73S 3108.44E 3042.67 N 49.50 E 4.16 641.85S 3124.25E 3059.58 N 52.30 E 6.34 628.80S 3140.31E 3076.68 N 55.31 E 6.60 616.55S 3157.06E 3094.39 N 57.87 E 5.93 604.43S 3175.43E 3113.72 8786.33 7324.83 7250.83 8816.69 7346.86 7272.86 8848.52 7369.89 7295.89 8883.61 7395.25 7321.25 8915.46 7418.09 7344.09 43 17 43 39 43 39 43 47 44 33 N 61.11 E 7.25 593.70S 3193.64E 3132.76 N 64.15 E 6.98 584.11S 3212.18E 3152.04 N 67.10 E 6.40 575.04S 3232.19E 3172.73 N 71.31 E 8.30 566.43S 3254.85E 3196.04 N 73.56 E 5.48 559.74S 3276.01E 3217.68 8947.02 7440.52 7366.52 8978.75 7462.94 7388.94 9008.81 7484.00 7410.00 9038.15 7504.31 7430.31 9068.47 7525.01 7451.01 44 52 45 12 45 51 46 31 47 23 N 77.53 E 8.91 554.20S 3297.50E 3239.57 N 79.64 E 4.81 549.76S 3319.51E 3261.86 N 82.95 E 8.16 546.52S 3340.70E 3283.26 N 85.69 E 7.10 544.43S 3361.77E 3304.42 N 88.32 E 6.96 543.27S 3383.89E 3326.56 9100.19 7546.33 7472.33 9132.10 7567.48 7493.48 9163.07 7587.89 7513.89 9193.39 7607.85 7533.85 9225.79 7629.22 7555.22 48 9 48 47 48 46 48 52 48 34 S 88.63 E 7.51 543.21S 3407.37E 3349.96 S 85.62 E 7.35 544.41S 3431.22E 3373.63 S 82.85 E 6.73 546.75S 3454.39E 3396.53 S 81.41 E 3.59 549.88S 3476.99E 3418.79 S 80.73 E 1.81 553.66S 3501.05E 3442.44 9259.13 7651.35 7577.35 9291.56 7672.92 7598.92 9323.33 7694.03 7620.03 9353.60 7714.17 7640.17 9384.85 7735.19 7661.19 48 15 48 20 48 24 48 12 47 13 S 80.49 E t.10 557.73S 3525.65E 3466.62 S 82.21 E 3.97 561.37S 3549.59E 3490.17 S 83.49 E 3.02 564.32S 3573.15E 3513.40 S 85.03 E 3.86 566.58S 3595.64E 3535.61 S 83.92 E 4.07 568.81S 3618.65E 3558.36 9416.05 7756.71 7682.71 9446.70 7778.60 7704.60 9478.08 7801.94 7727.94 9509.63 7826.35 7752.35 9541.43 7851.78 7777.78 45 32 43 16 40 37 38 1 35 43 S 83.25 E 5.64 571.33S 364i.09E 3580.51 S 82.80 E 7.48 573.93S 3662.37E 3601.50 S 81.02 E 9.26 576.87S 3683.14E 3621.95 S 80.64 E 8.24 580.06S 3702.87E 3641.35 S 80.86 E 7.24 583.13S 3721.71E 3659.86 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU / 13-06A 500292064201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010498 MWD SURVEY JOB NUMBER: AKMW80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASYJ% INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9572.27 7877.08 7803.08 33 57 S 82.07 E 6.16 9601.83 7901.88 7827.88 31 58 S 81.44 E 6.83 9634.23 7929.70 7855.70 29 38 S 80.31 E 7.41 9663.54 7955.45 7881.45 27 25 S 79.70 E 7.61 9695.22 7983.85 7909.85 25 6 S 79.73 E 7.35 585.74S 3739.13E 3677.00 588.05S 3755.04E 3692.67 590.67S 3771.42E 3708.77 593.10S 3785.21E 3722.31 595.60S 3799.00E 3735.84 9727.00 8012.82 7938.82 23 27 S 81.19 E 5.52 9756.96 8040.47 7966.47 21 51 S 84.35 E 6.71 9788.72 8070.08 7996.08 20 30 S 86.31 E 4.77 9818.66 8098.20 8024.20 19 36 S 87.54 E 3.32 9850.58 8128.47 8054.47 17 23 S 88.51 E 7.02 597.77S 3811.88E 3748.49 599.24S 3823.32E 3759.77 600.18S 3834.76E 3771.08 600.73S 3845.01E 3781.26 601.08S 3855.13E 3791.31 9881.79 8158.40 8084.40 15 24 N 89.39 E 6.62 9910.53 8186.24 8112.24 13 22 S 89.68 E 7.14 9942.46 8217.42 8143.42 11 20 S 87.64 E 6.50 9974.66 8249.06 8175.06 10 7 S 85.82 E 3.93 10008.67 8282.56 8208.56 9 43 S 85.87 E 1.15 601.16S 3863.94E 3800.08 601.14S 3871.08E 3807.20 601.29S 3877.91E 3813.99 601.62S 3883.89E 3819.93 602.05S 3889.74E 3825.72 10039.20 8312.67 8238.67 9 15 S 84.17 E 1.82 10067.16 8340.26 8266.26 9 19 S 85.72 E .93 10098.79 8371.51 8297.51 8 33 S 85.52 E 2.40 10129.28 8401.68 8327.68 8 2 S 87.81 E 2.02 10158.02 8430.16 8356.16 7 29 S 84.86 E 2.36 602.48S 3894.75E 3830.68 602.88S 3899.25E 3835.12 603.26S 3904.15E 3839.97 603.52S 3908.54E 3844.33 603.76S 3912.41E 3848.17 10189.80 8461.67 8387.67 7 20 S 81.24 E 1.54 10222.80 8494.41 8420.41 7 7 S 75.41 E 2.31 10254.11 8525.48 8451.48 6 59 S 69.52 E 2.35 10284.86 8556.00 8482.00 6 55 S 68.77 E .35 10316.05 8586.97 8512.97 6 40 S 65.47 E 1.49 10346.47 8617.17 8543.17 7 20 S 66.68 E 2.22 10378.56 8648.94 8574.94 8 37 S 67.59 E 4.04 10411.38 8681.36 8607.36 9 15 S 70.86 E 2.47 10443.23 8712.79 8638.79 9 21 S 73.51 E 1.37 10458.7! 8728.07 8654.07 9 22 S 76.76 E 3.42 604.25S 3916.48E 3852.18 605.09S 3920.55E 3856.17 606.25S 3924.21E 3859.72 607.57S 3927.70E 3863.08 609.01S 3931.10E 3866.35 610.51S 3934.49E 3869.61 612.24S 3938.60E 3873.56 6t4.05S 3943.37E 3878.16 615.62S 3948.27E 3882.91 616.27S 3950.71E 3885.28 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3998.48 FEET AT SOUTH 81 DEG. 8 MIN. EAST AT MD = 10458 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 85.20 DEG. TIE-IN SURVEY AT 8,490.29' MD WINDOW POINT AT 8,506.00' MD PROJECTED SURVEY AT 10,458' MD DRILL TD AT 11,094.00' MD CORE TD AT 10,848.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU ? 13-06A 500292064201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010498 JOB NUMBER: AKMW80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN i000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8490.29 7099.97 7025.97 9490.29 7811.28 7737.28 10458 . 71 8728 . 07 8654 . 07 717.42 S 3047.64 E 578.11 S 3690.91 E 616.27 S 3950.71 E 1390.32 1679.01 288.69 1730.64 51.63 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / 13-06A 500292064201 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 010498 JOB NUMBER: AKMW80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8490.29 7099.97 7025.97 717.42 S 3047.64 E 1390.32 8585.55 7174.00 7100.00 673.81 S 3088.69 E 1411.55 21.23 8717.10 7274.00 7200.00 618.74 S 3153.89 E 1443.10 31.54 8854.21 7374.00 7300.00 573.58 S 3235.83 E 1480.21 37.11 8994.48 7474.00 7400.00 547.89 S 3330.54 E 1520.48 40.27 9142.00 7574.00 7500.00 545.04 S 3438.64 E 1568.00 47.52 9293.18 7674.00 7600.00 561.52 S 3550.79 E 1619.18 51.18 9440.35 7774.00 7700.00 573.39 S 3658.04 E 1666.35 47.17 9568.54 7874.00 7800.00 585.45 S 3737.05 E 1694.54 28.19 9684.29 7974.00 7900.00 594.76 S 3794.34 E 1710.29 15.75 9792.90 8074.00 8000.00 600.26 S 3836.20 E 1718.90 8.62 9897.92 8174.00 8100.00 601.14 S 3868.04 E 1723.92 5.02 9999.99 8274.00 8200.00 601.94 S 3888.27 E 1725.99 2.07 10101.31 8374.00 8300.00 603.29 S 3904.52 E 1727.31 1.32 10202.23 8474.00 8400.00 604.52 S 3918.04 E 1728.23 .92 10302.99 8574.00 8500.00 608.39 S 3929.69 E 1728.99 .75 10403.92 8674.00 8600.00 613.65 S 3942.26 E 1729.92 .94 10458.71 8728.07 8654.07 616.27 S 3950.71 E 1730.64 .72 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA · PAGE i SHARED SERVICES DRILLING PBU / 13-06APB1 500292064270 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 121997 MWD SURVEY JOB NUMBER: AK~80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6896.00 5878.75 5804.75 43 49 S 68.77 E .00 1169.81S 2230.72E 807.45 6958.00 5923.50 5849.50 43 46 S 68.78 E .08 1185.35S 2270.73E 825.69 6995.43 5950.53 5876.53 43 43 S 68.78 E .17 1194.72S 2294.85E 836.69 7027.09 5973.43 5899.43 43 39 S 72.76 E 8.68 1201.92S 2315.49E 846.66 7057.79 5995.65 5921.65 43 38 S 76.73 E 8.93 1207.49S 2335.93E 857.61 7088.65 6018.01 5944.01 43 31 S 80.80 E 9.10 1211.63S 2356.79E 869.84 7119.67 6040.47 5966.47 43 42 S 84.95 E 9.24 1214.28S 2378.01E 883.37 7150.10 6062.44 5988.44 43 54 S 89.07 E 9.40 1215.38S 2399.03E 897.83 7181.33 6085.17 6011.17 42 41 N 86.68 E 10.12 1214.94S 2420.44E 913.63 7211.76 6107.78 6033.78 41 21 N 82.55 E 10.08 1213.04S 2440.71E 929.61 7242.98 6131.43 6057.43 40 9 N 77.96 E 10.34 1209.60S 2460.79E 946.52 7272.71 6154.44 6080.44 38 27 N 75.49 E 7.80 1205.29S 2479.11E 962.76 7304.66 6179.52 6105.52 38 3 N 74.54 E 2.21 1200.17S 2498.22E 980.12 7335.43 6203.75 6129.75 38 5 N 72.66 E 3.77 1194.82S 2516.42E 996.99 7368.48 6229.73 6155.73 38 13 N 73.16 E 1.03 1188.82S 2535.94E 1015.26 7397.78 6252.69 6178.69 38 35 N 69.97 E 6.87 1183.06S 2553.20E 1031.73 7429.22 6277.20 6203.20 38 57 N 67.40 E 5.25 1175.90S 2571.54E 1049.94 7459.98 6301.05 6227.05 39 22 N 67.14 E 1.44 1168.40S 2589.46E 1068.09 7491.30 6325.24 6251.24 39 31 N 65.45 E 3.46 1160.40S 2607.68E 1086.79 7521.93 6348.79 6274.79 39 59 N 62.41 E 6.53 1151.79S 2625.27E 1105.46 7553.24 6372.72 6298.72 40 17 N 61.01 E 3.04 1142.22S 2643.04E 1124.93 7584.59 6396.53 6322.53 40 52 N 61.85 E 2.57 1132.47S 2660.95E 1144.62 7616.50 6420.60 6346.60 41 12 N 59.02 E 5.91 1122.13S 2679.17E 1164.94 7650.12 6445.99 6371.99 40 42 N 55.31 E 7.39 1110.20S 2697.68E 1186.57 7679.26 6468.15 6394.15 40 17 N 53.25 E 4.79 1099.15S 2713.04E 1205.31 7708.61 6490.60 6416.60 39 51 N 52.25 E 2.66 1087.71S 2728.08E 1224.09 7742.52 6516.54 6442.54 40 19 N 48.36 E 7.52 1073.77S 2744.87E 1245.87 7771.01 6538.42 6464.42 39 19 N 47.85 E 3.69 1061.58S 2758.46E 1264.11 7801.95 6562.42 6488.42 38 56 N 43.24 E 9.49 1047.92S 2772.39E 1283.62 7833.55 6587.09 6513.09 38 27 N 40.87 E 4.94 1033.25S 2785.62E 1303.32 7863.31 6610.48 6536.48 37 56 N 39.57 E 3.20 1019.21S 2797.50E 1321.61 7893.04 6633.91 6559.91 37 59 N 37.62 E 4.04 1004.91S 2808.91E 1339.73 7928.59 6661.91 6587.91 38 7 N 37.76 E .46 987.57S 2822.31E 1361.40 8020.48 6734.37 6660.37 37 45 N 40.33 E 1.77 943.69S 2857.89E 1417.42 8114.74 6808.73 6734.73 38 4 N 38.42 E 1.29 898.92S 2894.63E i474.91 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALAS_WA PAGE 2 SHARED SERVICES DRILLING PBU / 13-06APB1 500292064270 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 121997 MWD SURVEY JOB NUMBER: AKMW80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8209.75 6883.67 6809.67 37 47 8303.47 6957.16 6883.16 38 54 8397.19 7029.19 6955.19 40 40 8490.29 7099.64 7025.64 40 58 8587.77 7173.06 7099.06 41 17 N 38.61 E .31 853.22S 2931.00E N 38.85 E 1.18 807.86S 2967.38E N 43.06 E 3.44 762.62S 3006.70E N 40.77 E 1.64 717.34S 3047.35E N 39.79 E .73 668.42S 3088.80E 1532.77 1590.40 1650.07 1710.74 1774.50 8678.59 7241.04 7167.04 8775.56 7313.51 7239.51 8866.80 7382.38 7308.38 8960.26 7453.35 7379.35 9053.23 7523.60 7449.60 41 47 41 28 40 30 40 40 41 9 N 41.50 E 1.36 622.73S 3128.03E N 41.24 E .37 574.38S 3170.61E N 38.94 E 1.97 528.61S 3209.15E N 38.55 E .33 481.19S 3247.21E N 40.04 E 1.17 434.07S 3285.78E 1834.42 1898.60 1958.08 2018.35 2078.78 9149.04 7596.11 7522.11 9241.06 7666.31 7592.31 9337.17 7740.59 7666.59 9430.99 7814.04 7740.04 9522.05 7884.81 7810.81 40 28 40 4 38 41 38 15 39 43 N 38.48 E 1.28 385.58S 3325.41E N 38.92 E .53 339.15S 3362.61E N 38.82 E 1.45 291.67S 3400.88E N 38.12 E .66 245.98S 3437.19E N 37.91 E 1.63 200.84S 3472.47E 2140.92 2199.88 2260.34 2318.15 2374.83 9615.78 7954.02 7880.02 9708.51 8019.48 7945.48 9802.71 8087.13 8013.13 9894.65 8154.85 8080.85 9987.26 8222.45 8148.45 45 2 45 8 43 2 42 2 44 11 N 41.30 E 6.18 152.25S 3512.80E N 42.63 E 1.02 103.42S 3556.71E N 42.87 E 2.23 55.29S 3601.20E N 40.96 E 1.78 9.04S 3642.73E N 38.35 E 3.01 39.70N 3683.10E 2437.55 2503.03 2568.43 2630.41 2693.26 10081.08 8290.08 8216.08 43 34 10115.13 8315.38 8241.38 40 26 10145.18 8338.72 8264.72 37 36 10175.84 8363.53 8289.53 34 21 10206.05 8388.85 8314.85 31 41 I023U.99 8416.39 8342.39 10269.16 8443.66 8369.66 10302.96 8474.20 8400.20 10336.09 8502.74 8428.74 10362.01 8526.19 8452.19 29 8 28 51 28 25 26 12 24 10 N 38.28 E .66 90.72N 3723.41E N 37.66 E 9.27 108.68N 3737.43E N 37.51 E 9.42 123.67N 3748.97E N 38.67 E 10.83 137.86N 3760.08E N 40.73 E 9.59 150.53N 3770.59E N 42.33 E 8.35 162.64N 3781.30E N 41.27 E 1.91 173.90N 3791.37E N 41.56 E 1.27 186.41N 3802.41E N 42.39 E 7.01 197.37N 38t2.26E N 42.96 E 7.93 205.48N 38i9.74E 2757.65 2780.19 2798.88 2816.71 2833.05 2849.17 2864.23 2880.85 2895.55 2906.55 10392.56 8554.29 8480.29 10423.73 8583.38 8509.38 i045~.65 8613.58 8539.58 10487.39 8643.91 8569.91 105!9.14 86?4.5i 8600.51 22 1 19 57 17 47 16 25 14 31 N 44.51 E 7.28 214.15N 3828.02E N 43.45 E 6.78 222.i8N 3835.77E N 43.27 E 6.74 229.68N 3842.86E N 41.52 E 4.64 236.57N 3849.16E N 40.38 E 6.03 242.97N 3854.72E 2918.52 2929.68 2939.99 2949.30 2957.73 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU / 13-06APB1 500292064270 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 121997 MWD SURVEY JOB NUMBER: AKMW80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10549.19 8703.72 8629.72 12 30 N 40.00 E 6.73 10628.00 8780.66 8706.66 12 30 N 40.00 E .00 248.33N 3859.25E 2964.72 261.41N 3870.22E 2981.68 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3879.04 FEET AT NORTH 86 DEG. 8 MIN. EAST AT MD = 10628 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 46.37 DEG. TIE-IN SURVEY AT 6,896.00' MD WINDOW POINT AT TOP OF WHIPSTOCK 6,958.00' MD PROJECTED SURVEY AT 10,628.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU / 13-06APB1 500292064270 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 121997 JOB NUMBER: AKMW80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 6896.00 5878.75 5804.75 7896.00 6636.25 6562.25 8896.00 7404.58 7330.58 9896.00 8155.86 8081.86 10628.00 8780.66 8706.66 1169.81 S 2230.72 E 1003.47 S 2810.02 E 513.86 S 3221.07 E 8.36 S 3643.32 E 261.41 N 3870.22 E 1017.25 1259.75 242.50 1491.42 231.66 1740.14 248.73 1847.34 107.19 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE SHARED SERVICES DRILLING PBU / i3-06APBi 500292064270 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 121997 JOB NUMBER: AKMW80047 KELLY BUSHING ELEV. = 74.00 FT. OPERATOR: ARCO ALASKA INC iNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6896.00 5878.75 5804.75 1169.81 S 2230.72 E 7027.88 5974.00 5900.00 1202.01 S 2316.03 E 7166.03 6074.00 6000.00 1215.27 S 2409.99 E 7297.64 6174.00 6100.00 1201.33 S 2494.05 E 1017.25 1053.88 36.63 1092.03 38.15 1123.64 31.61 7425.10 6274.00 6200.00 1176.90 S 2569.15 E 7554.92 6374.00 6300.00 1141.70 S 2643.98 E 7686.93 6474.00 6400.00 1096.18 S 2717.00 E 7816.83 6574.00 6500.00 1041.10 S 2778.78 E 7943.97 6674.00 6600.00 980.06 S 2828.13 E 1151.10 27.46 1180.92 29.82 1212.93 32.01 1242.83 29.90 1269.97 27.14 8070.63 6774.00 6700.00 920.18 S 2877.69 E 8197.51 6874.00 6800.00 859.08 S 2926.32 E 8325.18 6974.00 6900.00 797.28 S 2976.09 E 8456.32 7074.00 7000.00 734.21 S 3032.80 E 8589.02 7174.00 7100.00 667.78 S 3089.33 E 1296.63 26.67 1323.51 26.88 1351.18 27.66 1382.32 31.15 1415.02 32.70 8722.78 7274.00 7200.00 600.67 S 3147.53 E 8855.78 7374.00 7300.00 534.18 S 3204.66 E 8987.49 7474.00 7400.00 467.31 S 3258.27 E 9119.98 7574.00 7500.00 400.35 S 3313.67 E 9251.11 7674.00 7600.00 334.12 S 3366.67 E 1448.78 33.76 1481.78 33.00 1513.49 31.71 1545.98 32.49 1577.11 31.14 9379.96 7774.00 7700.00 270.83 S 3417.62 E 9507.99 7874.00 7800.00 207.93 S 3466.95 E 9644.06 7974.00 7900.00 137.22 S 3526.01 E 9784.75 8074.00 8000.00 64.28 S 3592.86 E 9920.57 8174.00 8100.00 4.23 N 3654.09 E 1605.96 28.85 1633.99 28.03 1670.06 36.07 1710.75 40.69 1746.57 35.82 10058.89 8274.00 8200.00 78.72 N 3713.94 E 10188.40 8374.00 8300.00 143.21 N 3764.47 E 10303.73 8474.00 8400.00 186.33 N 3802.34 E 10413.73 8574.00 8500.00 219.67 N 3833.39 E 10518.61 8674.00 8600.00 242.86 N 3854.63 E 1784.89 38.32 1814.40 29.51 1829.73 15.34 1839.73 9.99 1844.61 4.88 10628.00 8780.66 8706.66 261.41 N 3870.22 E 1847.34 2.73 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) 'POINTS ARCO ALASKA. INC. 13-06A Core chip sample descriptions 1c/7 -214' Core # 1: 10.5___~_- 10.542' MD Lower Kineak 0.520' - ~0.523' ~ Dark gray to black, flzm to hard, slightly carbonaceous. trace tifin siltstone stringers, abundant pyritc clusters. Sao River: MD 10,523', SS-87}$' v 10,523'- i 0.524' Black. modera'tely firm. carbonatiotxs, trace small black inclusions, trace disseminated pyrite, trace small vertical fractures wi~h bleeding oil. 10,524' - 10.526' Sb. ly $1tst: Light to dark brown, siky to very fine tower sandstone, well 5oned. 30% glauconite in broad bands, abundant disseminatcd pyrite, trace phosphatic noduals, trace single coarse upper quartz gra~. trace small parallel silica filled fractures, predominateb' tight, trace brown oil stain, dull gold fluoresence, siow diffused cut. 0.526' - 10.536' Sandstone' Lig}a gray to brovca, vet)' ~me lower to very fine upper, well sorted, predominaxely subangular, well sorted, silica cemented, gtaucomtic, scattered trace disseminated p)xite. traca large nodu~ (po~ibly siderite), bm-sm patchy oil stain, dull yello~-fluoresenee, bright yellow cut. 10,536'- 10.541' Sands[one: Bro~a~ to light gray. very. fine upper to very fine lower, well sorted, subangular, slight trace subrounded grains, silica cemented, glauconitic, scattered trace siderite noduals, trace soft white angular ff ~ggn'tents (possible aitered tbssil fragmems), thir to good porosity, massive dull yellow/gold tluoresence, bright yellow cut. 10.541'- 10.542' ~ As above, slight trace siltstone in .samvle. 13-06A CORE # 2: 10,624'- 10662',MD 0.624.4' Shiv $~; Black to dark gray, hard. abundant dis~minatcd pyrite. abundm'tt siderite cemem. slow diffused.cut.. l 0.024.4'- 10.633' Taz~. fine lower to very fine upper, well sorted, sulyan~ular. subrounded in part. silica cemented, scattered trace tripolitic chert, good ~rosity, dull yellow;gold fluorescence, dull yellow cut. trace thin p>zitic stringer at 10.628'. 10,633' - 10,634' Shale: LigJat gray/brown, thin bedded, with disseminated pyrite. slight trace tk~n silty streaks. ~('),63.~' - 10.640' Tan. medium upper to medium low, trace fine upper, moderate to well sorted, subangular, trace subroundcd. abundant ~ripotitie chert, scattered trace light gray to blactc lithic fragments, good porosity, dull gold fluoresence, bright yellow cut. 10.640' - 10,641.5' Sands-tone: Light to medium bruwn, medimn lower to medium upper. trace ve~' fmc lower, moderately sorted, subangular, trace trigolitic chert, bro~xt.patehy stain, dullyelioxv gold fluoresence, )clio'w/gold cut. 10641.5'- 10.642' Shale: Light gray brown, thin bedded, trace tan siltsto~. 10,642' - 10,6~' Light to medium browrt, fine upper, well sortec, trace tri~ljtie chert, good porosity, bright ycllov,/gold fltmresence, bright yellow,' to yellow/green cut. 10,644' - 10.645' Shale___; Light gray brown, thin sandstone stringers. 10,645'- 10.65I' S~dsto~ne: __ Tan, vet>- fine lower to silt)', wetisorted, bright yellow banded tluoresence, yen' slow difffi~sed cut. · 10.651'- 10.652' S3rldsto ne;. 'Fan to medium brown, coarse upper to medium iow. poorly sorted, suhangular, abundant white tripoiitic chert, trace tight gray chert, trace black to light gray lithic fi'agments. trace light gray. soft mud noduals, reD' good porosity, pmpont yellow/gold fluoresence, yello~':gold cut. - 0.6.... ~ 10,652' 1 'g'~ .' 'Fan. moderately soil slight trace scattered lower coar~ qua.rtz grainS. PRGE. 00:3 jAN ' g '98 12:ET 1907S5~0~84 10,652.5' - 10,658' '10.658'- i 0,659' 10.659' - 10.661' 10.661'- 10,662' 5~d~tonc: Shale' ~o Smpl' l,i~Ptt to mectiam brovm, fmc upper to tine iower, well sorted, subanguiar, angular in part, scattered white tripoiitic chert, occatior,axi trace small black lithie fragments, good porosity, dull _cold fluore~nce, dull yellow cut. Light sray brown, moderately sofL possible rip up mud clasps. Medium to light brown, m~ium upper to mcdium low. trace frae upl:z:r, modcrately sorted, trace to abundant white tril~ i/tic cher:, abundant to trace lithic fragments, dull gold to dull yellox~, :g,o-ld fluoresence, bright to dull yellow cut. Not recovered in core barrel. jAN 10 'gB l~:~B i~07~5~0~84 PAGE.004 13-06A C_ore # 3:10.662' - 10.724' MD 10.662' ](';.669 10.669'- 10.671' 10,671' - 10.672' 10.672'- 11').676' 10.676' - 10.679' 10.679' - ~0.688' 10.688' - 10.692' 10.692' - t 0.696' Sandstone: .5.~dslone: Siltstone: _Sandstone; Sandstone: Sandsto_n~ Sandstone: Ta: to '_light brov,.'n, medium tow to fine uplxr, moderate to welt sorted, trace tripoltic chert, trace lithic fra~.mtmts, trace ',,,~e tr~litic noduals, bright yellow fluoresence, bright yello x~,vbluc cm. Tan to light brown. ','eD' fine lowcr to veD, fine upper, well sorted, trace tripoLitic chert some nodular tripoliti= chert. lhir :o poor porosity, bright yei to yellow:gold fluorenenee, ligk: yellow/green cut. LigM brown to black, banded, trace black oil staining. patch.,,' fight yetlow fluoresence, light yellow/green cut. Tan to li,_mht bro,am, ,,'eD' fi.ne lower to very tine upper, tracc fine lower, well ,rotted. scattered trace tripoliti¢ cb. err, poor to l~ir porosity, bright yellow fluoresenee, light yellow/green cut. Light to medium brmvn, fine upper to medium iov,, moderate to well sorted, scattered white tripolitic chert, liir to good porosity, occational trace small shale lamination. bright yellow fluoresence, bright yellow green cut. Light to medium bro,,¥n, medium low to medium upi>er, well sorted, subangular, trace subrounded, abundant t~poiitic_ehe~, occational trace tripottic noduais, trace black to dark ~m-ay [itl'dc ffa.m'nents, bright yellow to yeliov,-/gold fluom~nce, gmad porosity, light yellow/green cut. Tan. gray brmvn, moderately soft. Tan. well sorted, light yellow/green fluorcsence, poor porosity, slow light green cut. L' ':ght brow medium up~r. well sorted, subangular, tmee trip__o_tRig_chert, fair Lo_go~$ity. dull yellow/gold fluoresence, bright yellow to yellow/green cut. Medium to dark bm,a,~ medium up.t~er to medium low. well sorted, trace tripolitic chert, trace dark gray to black lithic fragments, trace thin shale laminations, trace tlfin silts'tone laminations, poor to good porosity, bright yetlov,::gold fluoresence, bright yellow to yellow/green cut. 10.69('>' - 10.699' ,Sanciston=: _ 10.699'- I0.700' 10.700' - 10.703' Sana.srone' I0.703'- 10.710' Sandstone_: 10.710'- 10.716' Sandstone: 10.716'- 10.719' ~andstone: 10.719'-10.724' ~ FIJI.L CORE Rli;COX'ER't~" Light to medium brman, very linc tower to vet3' tine uPlxr, sihy in part. ,,,,'ell sorted, lhir porosity, dull gold fluoresencc. bright ,,'allow cu:. As above, trace biacko il stained vertical fracture. Tan to light brown, very fine lower to veD' tine u!a~r, well sorted, trace tin.k-, siltstone laminations, fair porosny, dull gold fluorescn~, light yellow;'grccn cut. Tan to light brovcn, trace medium brown, medium upper to fine upper, moderately sorted, abundant tripolitic chert. trace lithic iYat, ments, trace thin shale laminmions, scatte~ trace rip up mud cla~ps, dull gold fluoresenc¢, li~t yetlow/'green ct::. Light brown, m~dium upper to medium low, trace fine upper, moderatc to well sorted, trace tripoliti¢ chert. occationa[ trace ti'tin shalc [amination.q. fair porosity, dull yeliowigold fluoresence, light yellow/green cut. Light to medium brown, fine upper to medium low, well sorted, subanguiar, trace tripolitic chert, slight tra~"e small lithic fragments. Iiair to good pomsit>-, slight trace small shalc lamination, dull gold fluoresence, yellowisreu-n cut. l.ight to medium brown, fine lower to very fine ~. trace ['me lower, moderate to well sorted, trace trilmlili¢ chert. slight trace lithic fi'agments, dull gold flaoresenee, light yeliow cut. 13-06A CORE # 4: 10,724' - 10,786' MD 10.72-1'- t0.729' Sanaaone: Light brown :o tan. ,,'eD' tine upper to fine upper, mocicmte to ,,,,'ell sorteci, subanguiar, angu 'lar ir. part. thir tripotitic chert, fair to good porosity, bright yellow to yeliov~.-'gold lluoresence, light yello~::grcen cut. 10.729' - 10.734' $~dstonc: Gray brown, thin bedded. Tan to lion brown, yen, fine lower to very fine upper, silty in part. well sorted, trace tripolitic chert noduals, dull yellow.,gold flumesencc, yellow;green cut. u. ,_~,, 10.736' 5halc: Gray bro,,~u~, firm. brittle, trace siltsmnc stringers. 10.736' - 10.738' Light brown, reD' ti.nc iov.-'er to vet)' fine upper, well ~rtcd. trace tripoltie chert, fair porosity, trace scattered black stain. trace black stain on vertical fracture, dull gold fluoresence. light green cut. 10.738' - 10.741' (,ira)' brown, modeLately firm. si' ,tgla~' silt),. As above. 10.741'- l 0.7J, R' 10.748' - 10.752' $1mdstorle: Tan to light brown, frae upper to medium iow. moderate to ,,,,'eli sorted, trace tripoiitic chert, trace snudl iithic fi-agments, fair to good porosity, bright yellow pin point fluoresence, trace Light yellow/green cut. # Light brown to tan. fine upper to fine lower, moderate to ',,,'ell sorted, aimndant small tripolitic chert nociuals, slight trace small chert pebbles, dull gold fluoresence, light )~llow!green cut. l 0.752'- t0.761' Sandstone: Light brown to tan. fine lower to fmc upper, trace medium lower, moderate to well sorted, trace tripolitic chert, lhir to good porosity, dull gold fluoresence, yellow/green cut. 10.761' - l 0.764' ~ha!e: Gray brown, moderately t-a'm, thin bedded, grading into sandstone - as above. 10.764' - 10.768' Medium to light brown, medium lower to medium upper. trace fi.ne upper, moderately sorted, abundant tripolitic chert, trace black iithic fragrnems, scattered black oil stain. slight trace pin point yello,.,,' Iluorescnce. dull gold cu:. jAN 10 '98 12:30 I~076580E84 0.768' - 10.77 10.771'-'0.772' 10.772'- 10.780' l 0.780'- 10.782' 10.782'- 10.786' S:-mdsmnc: SandsTone: .Medium to dark brown, medium tow-er to fine upper, fine lower in part. moderate to welt sorted, abundant triOotitic chert..qcattered trace small pebbles. 30% black oil in matrix.- ~race scattered mud clasps, no visible tluoresencc. veliow."gold cut. Dark brown, tine upper to medium lower, scattered trace medium upper to coarse upper..rmorly sorted, trace tripolitic chert. 30% back oil,. good porosib', dull gokt pin point tlunresenc, e, yellow/green cut. Dark brown. ','er3_' fine upper to fine lower, grading toward medium lower, moderate to well sorted, trace tri~litic chert, fair to good porosity, 60% black oil in matrix, bright yeilow.:gold fluaresence, yellow/green cut. Dark brown, black in ~art. fine upper to medicm lower, well sorted, trace tnpolitic chert, fair to 8God porosity. 80% black oil. yen.' slight trace dull gold pin point fluoresence, yellow.."green cat. [)ark brown, medium upper to medium lower, trace fine uppt:r. ',~,ell sorted, abundant trivolitic chert. 70 - $0% black oil in matrix. ,,'e~' slight trace pm poim fluorv~ence, yellow: green cut. FULL CORE RECOVERY' JAN 10 '98 12:~1 l_~'BTBSB0884 PAGE.~08 l~5-06A CORE # 5: 10,786' - 10.848' MD 0.786'- 10.789' Sand_stODe: Dark brown, fine up~r to medium lower. :race medium upper, moderately ..~rted. trace trit~olitic chert, trace black lithic fi'agments, fair to good porosity, scattered dull gold fluoresence, b '~ri4~ vel.to,,: ~oid to yellow/green cut. ESTIMATED TOP HOT :a.--? MD: 10,789' SS: -9086' I0.789'- 1(1.795' .Sandstone: Black to dark bro~,~.'n, medium lower to fine upper, trace coarse lower to medium upper, moderate to poor .ly sorted, trace ?ebbles. abundant t.'-i~litic chert trace tripolitic chert nodu,~ 98% black oil in matrix, slight trace pin point gold fluoresence, trace dull cold cu:. 10.795' - 10.802' ~dstone: Black to dark brow-n, me, mm lower to medium upper, moderaxely sorted, abundmlt tripolitic chert. 98 - 100% black oil in matrix, abun '-ae. nt tripoiitic chert, no visible fluoresence, yellow, gold :L', yetlo~v'green cut. 10.802'- 10.803' ~andslgne. Black to daxk brov.-n, fine lowcr to fine up, r, well sorted. poor :o fair porosity. 100% biack tar in matrix, no visible fluoresence, dull yellow:green cut. l 0.803' - 10.805' Saqd~tgne' Black to dark brown, coarse upper to coarse lower, medium upper m part, pooriy sorted, abundant tripolitic chert, trace bla~k lithic fragments, trace pebbles, trace mud rip up clasps. 100% tar filled, no fluorcsence, ycliow/gn..en cut. 10,805' - 10.807' ~andslo~e: Dark brown, gray brown, medium lower to medium upper, trace coarse lower, mocterateb' sorted, abundant tripolitic chem. abund tar. no visible fluoresence, yellow/green to Light green cut. 10,807' - 10.81 I' L'onel' -- Black to tan, coarse upper to medium lower, abundant I/g" to 1/2" pebbles, massive '.ripoiitic chert, black tar. poorly sorted, trace large clav noduale :~'. 10.809'. 10.gl 1' IO.giT ~ Ligh~ gray, massive, sticky, swelling evolcanic ash?). 10.812'- 10.821' Black to mn. coarse upper to medium lower, scattered !/8" to 1/2" pebbles, poorly sonefl, poor to/good porosity, trace heax?- tar ,vn'e~s. trace cLzy noduals .?: 10.813'. 10.81 g'. PAGE. 009 JAN 10 '98 and 10.820'. no visible fluoresence, yellow/green cut. 10.821' - 11).822' .',;aqd ston_e; Medium brown, very fine upper to fine lower, well sorted. trace mud chuos. 80% tar filled, no visible tluoresencc, light TOP ZONE 3 ( 31N ) MD: 10.822' SS: -9019' I0.822'-10828' q~alc: 10.828'-!0.841' 5hale: TOP ZONE 31P Medium _re'ay browp_ fim'L slightly stilty in part. o¢cational trace scattere::[ pyrite. Medium to dark gray brown, moderately firm to firm, occational trace, thin siltstone stringers. MD: I0.841' SS:-9038' 10.841'- 10.842' C_p. llgll 10,842' - 10.844' 10.842,'- 10.848' .C-qllgii 1 '8" ' '"~" .poori. y sortcd, mc-'dium Pebble conglomerate, .. to ,,- , . attar ta ~ .u!~ex ~ pt:eaeat, trace thin shale stringer at base. Pebbles and cobbles increasing in size, 1/4" to i", xracc scattered rip up mud clasps. Cobbles no,.,.-up to 2 1/2". trace p~ite in sandstone mmrix. trace siderite cement noduais, scattered brown patchy stain. scattered dull gold fluorescnce, light yellow green to dull ~old, cut. FULL CORE RECOVERY __ spenn -sun ' D I:t I CI--I N G S I~ I:!~/I r- G S 17-Mar-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 ESS Survey for core section to TD Re: Distribution of Survey Data for Well 13-06A Dear LoriTaylor: ~(~t ~ ~/.~~ Enclosed are two survey hard copies. ~ Tie-on Survey: Window / Kickoff Survey: -F~ojected Survey: 10,254.11' MD n/a' MD 11,044.18' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 119O7 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 3/10/98 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape 13-06~ = 97078 ~/~_,-~/az-~c 980111 1 13-06J~. 97078 ~_~,._T~ 980111 I 1 ~3-0~ 97078 ~-~ 98oss[ I 1 ~3-0~ 97078 ~-3 ~.~.~ 9so[ii I 1 13-0~ 97078 ~ ~c 9so~ I 1 13-0~ 97078 s~ 9~0[~[ I 1 [3-0~ 9~078 ~~~= 9ao[~z I 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 !::~ I L_/I IM CS SIm I~! ~d I I-- I::::: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 c~" I - February 11, 1998 RE: MWD Formation Evaluation Logs D.S. 13-06A & 13-06A PB1, AK-MW-80047 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services. 5631 Silverado Way, #G, Anchorage, AK 99518 DS 13-06A · 2" x 5" MD Gamma Ray Logs: 50-029-20642-01 2" x 5" TVD Gamma Ray Logs' 50-029-20642-01 DS 13-06A PBI' 2" x 5" MD Gamma Ray Logs: 50-029-20642-70 2" x 5" TVD Gamma Ray Logs' 50-029-20642-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company r'l !::! I I_1_ I IM G S I~ I:! ~.~ I I-- E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. February 4, 1998 Attn.' Lori Taylor 3001morcupine Dr. ,,~~_.<7oc).,5Q. .-~ Anchorage, Alaska 99501 ~3"~- ,~. "~'~ MWD Formation Evaluation Logs - D.S. 13-06A & 13-06A PB 1, AK-MW-80047 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: Jim Galvin. Sperry-Sun Drilling Services, 5631 Silverado Way,//G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl//: 50-029-20642-01 & 50-029-20642-70. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company SAMPLE TRANSMITTAL TO: State of Alaska Oil & Gas Con. Comm. Anch., AK. OPERATOR: ARCO SAMPLE TYPE: CCC(STATE CHIPS) SAMPLES SENT: 10,520'- 10,542' (SAG RIVER) 10,-624'-10,848' (SADLEROCHIT) DATE: February 2, 1998 AIR BILL: AL864030 AFT:ABV08-02-02-01 CHARGE CODE:4J0-378 NAME: 13-06st APl NO: 500292064201 NUMBER OF BOXES: 4 SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: T. Archuleta RECEIVED BY: CC; ARCO ALASKA, INC. P. O. BOX 100360 ANCHORAGE, AK. 99510 ATTN: BAYVIEW GEOLOGIC FACILITY DAN PRZYWOJSKI ABV-100 DATE ¢2~ l-~'~ [C~,~ ~ ATO 1552 DFtl I_1--1 ~ G S I::::: F! ~J I I-- i~ S 29-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 13-06APB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,896.00' MD 6,958.00' MD 10,628.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ri I:t I I_1_ I I~1 I~ S E I:1~1 r' I:: S 29-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 13-06A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,490.29' MD 8,506.00' MD 10,458.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: DATE: David Johnst~ Chairmam-5~ Blair Wondzell, P. !. Supervisor FROM' Chuck Scheve, ¢.¢, SUBJECT: Petroleum Inspector FILE NO: January 9, 1998 agwkaife.doc BOPE Test Doyon 141 DS 13-06A PTD # 97-218 Friday January 9, 1998: I traveled to ARCOs DS13-06A well being drilled by Doyon Rig 141 and witnessed the weekly BOPE test on this well. As the attached AOGCC BOPE test report shows the test lasted 3 hours with no failures. The testing went well with good test procedures being employed by the Doyon crews. The rig was clean and all related equipment appeared to be in good working order. The location was well organized allowing good access to all areas of the rig. Summary: DS13-06A. Doyon 141, Attachment: I witnessed the weekly BOPE test on Doyon Rig 141 Drilling ARCOs 118198, test time 3 hours no failures agwkaife.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: DATE: 1/9/98 Drlg Contractor: Doyon ~ Rig No. ~4~ PTD # g7-218 Rig Ph.# 263-3101 Operator: SSD Rep.: Dave Burly Well Name: DS13-06A - Rig Rep.: Pat Karupa Casing Size: g 5/8 Set @ 6958 Location: Sec. 13 T. 1ON R. f4E Meridian Test: Initial Weekly x Other · UM Test MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK (Gen) Drl. Rig OK PTD On Location YES Hazard Sec. OK z Standing Order Posted YES , FLOOR SAFETY VALVES: Quan. Pressure P/F Upper Kelly ! IBOP I 250/5000 I P Lower Kelly / IBOP I 250/5000 I P Ball Type I 250/5000 p.. Inside BOP I 250/5000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F P 250/3000 250/5000 250/5000 250/5000 250/5000 250/5000 250/5000 N/A P P P P P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK - H2S Gas Detector OK OK , CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/5000 P 28 250/5000 Functioned Func. fioned P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3000 I 17 minutes 35 sec. 2 minutes 42 sec. OK Remote: OK 5 ~ 2250 Psi Psig. Number of Failures: 0 ,Test Time: 3,0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 Ill REMARKS: Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W'rtnessed By: Chuck Scheve F1-021L (Rev.12/94) agwkaife ....... STATE OF ALASKA ALASKA ,.,._ AND GAS CONSERVATION CON,,,,ISSION APPLICATION FOR SUNDRY APPROVAL :1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate ~2. Name of Operator 15. ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1643' NSL, 5199' WEL, SEC. 13, T10N, R14E, UM At top of productive interval Type of well: [] Development [] Exploratory F-~ Stratigraphic [] Service 6. Datum Elevation (DF or KB) Plan KBE = 74' 1030' NSL, 1217' WEL, SEC. 13, T10N, R14E, UM (Planned) At effective depth 1905' NSL, 1328' WEL, SEC. 13, T10N, R14E, UM At total depth 1021' NSL, 1115' WEL, SEC. 13, T10N, R14E, UM (Planned) 12. Present well condition summary Total depth: measured 10628 feet true vertical 8782 feet Effective depth: measured 10628 feet true vertical 8782 feet Plugs (measured) Junk (measured) 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 13-06A 9. Permit Number 97-218 10. APl Number 50-029-20642-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Whipstock set at 6988' Casing Length Size Structural Conductor 80' 20" Surface 2627' 13-3/8" Intermediate Production 6927' 9-5/8" Liner Cemented MD TVD 300 sx PF 110' 110' 2750 sx Fondu, 400 sx PF 'C' 2660' 2660' 500 sx Class 'G', 300 sx PF 'C' 6958' 5924' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A ORIGINAL RECEIVED DEC 24 I997 ~aska Oil & Gas Cons. Commi~e~ A~horage 13. Attachments [~ Description summary of proposal I~l Detailed operations program I~1 BOP sketch 14. Estimated date for commencing operation December 22, 1997 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas E~ Suspended Service Water & Gas Injector Contact Engineer Name/Number: B~?bfza, 564-5344 /¢ Prepared By Name/Number: 17.1 hereby certify that tb/Cforeping is tru/~d¢/~ect to the best of my knowledge Signed _/,'- .~ ~ I Dan Sto,tz ,~,.~~ ~--~ ~V ~ '- Titl~ s~-nior Drilling Engineer Commission Use Only Terrie Hubble, 564-4628 I Approval NO.,~ Conditions of Approval: Notify Commission so representative ,~.,~y witness Plug integrity /' BOP Test Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- di'lgi,qal Signed By ApprovedCOP~ommissioner' Approved by order of the Commission 0avid W. John.~t0.n. ~^, ...... I ~LI~1 I I'~.,~Y Form 10-403 Rev. 06/15/88 ~-t Date/0~, Submit In Triplicate BP EXPLORATION To: AOGCC From: Bob Kaluza, ODE, SSD MB 8-1 Well Plan Revision 13-06A Subject: Date: December 23, 1997 Well 13-06A was sidetrack drilled out of existing 9 5/8" casing into the Lower Ugnu Sands. The 8 1/2" hole was then directionally drilled with GEM (glycol enhanced mud) to the top of the Sag River formation. The GEM mud was used to inhibit the Kingak Shale formation while drilling and also in preparation for coring the Sag River, Shublik and Zone 4 formations. The top of the Sag River formation was the top of the core point. While circulating at the top of the Sag River formation at + 10,620', the hole started to packoff the drill string. The pipe was pulled out of the hole through several tight spots in the Kingak formation and the HRZ formation. A full gauge hole opener was run to ream through the tight spots without success. It was decided to abandon the lower section of the hole and spot a drill-off plug at + 8,550' to drill toward a new WAG injector target. The new target is 870' South and 140' East of the present target. Objective: Set a 750' MD Hi-Vis mud plug from + 9,700' to 8,950' MD. Then pump a two stage drill-off plug from + 8,950' to 8,350' MD. The 15.8 ppg first stage cement top will be at + 8,600' MD, and the 17.0 ppg second stage will be from 8,600' to 8,350' MD. WOC a total of 12 hrs. Directionally drill off of the cement plug with a 8 1/~,, PDC bit, MWD/GR assy to the new core point at the TSAG. Revision 1. RIH w/cement shoe on 5" DP to + 9,700'. Circ and condition mud. 2. Spot 150 bbl ( .0702 x 750' = 52.65 bbl x 200%), 400 funnel vis, 14 ppg Hi-Vis pill. POOH to + 8,950. Circ bottoms up. 3. Rig up to pump cement. Test lines. Pump 10 bbl water ahead, 240 sx (100 % excess, 8 1~,, hole) 15.8 ppg, Class 'G', 1.15 ft3/sx, .35% FL-33, .3% CD-32, .12% R-l, 1 ghs FP-6L, Batch mix. POOH to + 8,600'. Circ cement out. 4. Pump 10 bbl water ahead, 198 sx (100 % excess), 17 ppg, Class 'G', .997 ft3/sx, .17% FL-52, .8% CD- 32, .05% A-2, 1 ghs FP-6L, Batch mix. POOH to + 8,350'. Circ out cement. 5. POOH lay down cement BHA. 6. MU Rebuilt DS 70 PDC, MWD/GR 1.83 directional BHA (see BHA #2 original well plan). RIH tag cement, drill down to + 8,550', kick-off. 7. Directionally drill to TSAG as per new directional plan. Change out GEM mud to shale inhibited 10.5 ppg KCL mud after drilling out cement. 7200 - 7600 - 8000 - 8400- 8800 - 9200 - 9600- I I 2800 3200 Scale: linch = 400ff Shared Services Drilling DrillQuest' Propoaal Data for 13-06A NewTa/g (wpS) V~Ho~m~l~n: Well Well Measurement UnlU:R Nor[h Ref~: Tree North Vm-dc~ Secaon Desaq~x~Wea VefUcal Section Origin: 0.00 N,0.00 E Measured Incl. AzJm. VerUcal Depth Depth Northlngl Eastlngl Vertical Section 687,58 S 3073.06 E 3004.75 561.42 S 3413.63 E 3354.68 578.75 S 3611.20 E 3550.10 602.50 $ 3881.86 E 3817.83 611.29 S 3982.02 E 3916.90 620.23 S 4083.90 E 4017.67 Oogl$, Rate 8550.00 41.169 40.168 7145.02 9105.31 49.242 95.015 7550.~9 93~7.13 49.242 95.015 7721.93 ~927.73 10.000 95.015 81~9. g0 10506.7310.000 95.015 8770.00 11095.6&10.000 95.015 9350.00 7.000 0.000 7.000 0.000 0.000 10200.00 13..(~A T1 6776.60 2~1.95 N, 3~63.65 E 10400.00 0600.00 Poln~ 8770.00 611.2~ S, 39~2..02 E 10800.00 ~ 110oo.00 I 3600 I 4000 Vertical Section Shared Services Drilling DrillQuest' 300 Scale: linch = 300ft 2400 I Eastings 2700 3000 3300 3600 3900 4200 4500 I I ! I~ I I I 7' Uner 11208.51 9351.27~ 13-0~A T1 Ckc~ 8T/~.~O 2~1.~1 N. 3a6,1.~5 E 300 $700.00 8800.00 -3O0 -6O0 -1200 I 2400 Scale: linch = 300ft 13-06A New2 6770.0O 611.29 S, 39~_Q2 E 13-06A NewTarg (wps) I I I I I 2700 3000 3300 3600 3900 4200 Eastings I 4500 Reference is True North -300 -600 -9OO -1200 Sperry-Sun Drilling Services Proposal Report for 13-06A Rig - 13-06A NewTerg (wp8) Shared ServiCes Drilling Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOADS13 Measured Vertical Depth Incl. Azim. Depth Northings Eastings (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (ft) (o/looft) 8550.00 41.169 40.168 7145.02 687.58 S " 3073.06 E 3004.75 9105.31 49.242 95.015 7550.99 561.42 S 3413.63 E 3354.68 7.000 9367.13 49.242 95.015 7721.93 578.75 S 3811.20 E 3550.10 0.000 9927.73 10.000 95.015 8199.80 602.50 S 3881.86 E 3817.83 7.000 10506.73 10.000 95.015 8770.00 611.29 S 3982.02 E 3916.90 0.000 11095.68 10.000 95.015 9350.00 620.23 S 4083.90 E 4017.67 0.000 Ali data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from KOP and calculated along an Azimuth of 85.200° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11095.68ft., The Bottom Hole Displacement is 4130.72ft., in the Direction of 98.636° (True). . Targets associated with this wellpath Target Entry Coordinates Target 'i'VD Northings Eastings Target Name (ft) (ft) (ft) Shape Target Type 13-06A New2 8770.00 611.29 S 3982.02 E Point Geological Sperry-Sun Drilling Services Proposal Report for 13-06A Rig - 13-06A NewTarg (wpS) Shared Services Drilling Prudho6 Bay Unit Measured Depth fit) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8550.00 41.169 40.168 7071,42 7145.02 8600.00 40.724 45,467 7109,20 7182.80 8700.00 40.575 56.219 7185,16 7258.76 8800.00 41.415 66,822 7260,73 7334.33 8900.00 43.187 76.893 7334,78 7408.38 9000.00 45,777 86,182 7406.19 7479.79 9100.00 49.052 94.593 7473.92 7547.52 9105.31 49.242 95.015 7477,39 7550.99 9200.00 49.242 95.015 7539.21 7612.81 9300.00 49.242 95.015 7604.50 7678.10 9367.13 49;242 95.0t5 7648.33 7721.93 9400.00 46.941 95.015 7670.28 7743.88 9500.00 39,941 95,015 7742.84 7816.44 9600.00 32,941 95.015 7823.24 7896.84 9700.00 25.941 95,015 7910.27 7983.87 9800.00 18.941 95.015 8002.64 8076.24 9900.00 11.941 95,015 8098.97 8172.57 9927.73 10.000 95.015 8126.20 8199.80 10000.00 10.000 95.015 8197.36 8270.96 10100.00 10.000 95.015 8295.85 8369.45 10200,00 10.000 95,015 8394.33 8467.93 10300.00 10,000 95.015 8492.81 8566.41 19400.00 10.000 95.015 8591.29 8664.89 10500.00 10.000 95.015 8689.77 8763.37 10506,73 10.000 95.015 8696.40 8770.00 4' ,~.. Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) ('/l OOft) (ft) 687.58 S 3073.06 E 5931101.18 N 690393.22 E 663.56 S 3095.31E 5931125.75 N 690414.86 E 7.000 622.55 S 3145.66 E 5931168.00 N 690464.18 E 7.000 591.41S 3203.17 E 5931200.55 N 690520.90 E 7.000 570.60 S 3266.98 E 5931222.93 N 690584.17 E 7.000 560.44S 3336.14 E 5931234.81N 690653.06 E 7.000 561.08 S 3409.63 E 5931235.99 N 690726.55 E 7,000 561.42 S 3413.63 E 5931235.75 N 690730.55 E 7.000 567.69 S 3485.09 E 5931231.26 N 690802.14 E 0.000 574.31S 3560.54E 5931226.51N 690877.74 E 0,000 578.75 S 3611.20 E 593'1223.33 N 690928.49 E 0.000 580.89 S 3635.57E 5931221.79 N 690952.90 E 7,000 586.90S 3704.02 E 5931217.49 N 691021.48 E 7,000 592.09 S 3763.16 E 5931213.77 N 691080.73 E 7,000 596.38 S 3812.09 E 5931210.69 N 691129.76 E 7.000 599.72 S 3850.10 E 5931208.30 N 691167.83 E 7.000 602.04S 3876.60 E 5931206.63 N 691194.39 E 7.000 602.50 S 3881.86 E 5931206.30 N 691199.66 E 7.000 603.60 $ 3894.36 E 5931205.51 N 691212.18 E 0.000 605.12 $ 3911.66 E 5931294.43 N 691229.51E 0.000 606,64S 3928.96 E 5931203.34N 691246.84E 0.000 608.15 S 3946.26 E 5931202.25 N 691254.17 E 0.000 609.67 S 3963.55 E 5931201.16 N 691281.50 E 0.000 611.19 S 3980.85 E 5931200.07 N 691298.83 E 0.000 611.29 S 3982.02 E 5931200.00 N 691300.00 E 0.000 Alaska State Plane Zone 4 PBU_EOA DS t 3 Comment 3094.75 3028.93 f..,~.~ ~ ,~ ~',~ 3082.53--~' 3142.44 3207.77 32~.55 33~.7~. "~ 33~.~ ~25.36 3~0.00 35~.10 3574.21 3~1.92 3700.41 3748.82 38~2.63~ 3817.83 3830.19 ~ ~ ~.53 3898.~ 3915.75 3916.90 Targe~ 13~6A Ne~. Geol~i~l I Continued... -1- DdllQuest Sperry-Sun Driilin Services Proposal Report for 13-06A Rig- ~3-06A NewTarg (WPs) Shared Services Drilling Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (fi) (fi:) (°/'~OOft) (fi) 10600.00 10.000 95.015 8788.25 8861.85 10700.00 10.000 95.015 8886.73 8960.33 10800.00 10.000 95.015 8985.21 9058.81 10900.00 10.000 95.015 9083.69 9157.29 11000.00 10.000 95.015 9182.17 9255.77 11095.68 10.000 95.015 9276.40 9350.00 612.71 S 3998.15 E 5931198.99 N 691316.16 E 0.000 3932.86 614.23 S 4015.45 E 5931197.90 N 691333.49 E 0.000 3949.97 615.74 S 4032.75 E 5931196.81 N 691350.82 E 0.000 3967.08 617.26 S 4050.05 E 5931195.72 N 691368.16 E 0.000 3984.19 618.78 S 4067.34 E 5931194.63 N 691385.49 E 0.000 4001.30 620.23 S 4083.90 E 5931193.59 N 691402.07 E 0.000 4017.67 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from KOP and calculated along an Azimuth of 85.200° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11095.68ft., The Bottom Hole Displacement is 4130.72ft., in the Direction of 98.636° (True). Comment · 22 December, 1997 - 15:58 - 2 - TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 26, 1997 James Smith Senior Drilling Engineer, Acting BP Exploration (Alaska), Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 13-06A BP Exploration (Alaska) Inc. Permit No: 97-218 Sur. Loc.: 1643'NSL, 5199'WEL, Sec. 13, T10N, R14E, UM Btmhole Loc: 1963'NSL, 1298'WEL, Sec. 13, T10N, R14E, UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W~ohnston Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC' Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA ,.,.L AND GAS CONSERVATION COIVr[;IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator !5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 74' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028315 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1643' NSL, 5199' WEL, SEC. 13, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 1948' NSL, 1307' WEL, SEC. 13, T10N, R14E, UM 13-06A Attotal depth 9. Approximate spud date Amount $200,000.00 1963' NSL, 1298' WEL, SEC. 13, T10N, R14E, UM 12/01/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028330, 1298'I No Close Approach 2560 11200' MD / 9349' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 7000' MD Maximum Hole Angle 40.4° Maximum surface 2487 psig, At total depth O'VD) 8800' / 3367 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 27# L-80 BTC-Mod 4350' 6850' 6062' 11200' 9353' 817 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Totaldepth: measured 11800 feet Plugs(measured) Fillat11109'MD(07/18/92)ORIGINAL true vertical 9619 feet Effective depth: measured 11109 feet Junk (measured) true vertical 9084 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 300 sx PF 110' 110' Surface 2627' 13-3/8" 2750 sx Fondu, 400 sx PF 'C' 2660' 2660' Intermediate Production 10721' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 10752' 8809' Liner 1349' 7" 425 sx Class 'G' RE . ¥ED 9613' PeRoration depth' measured 10794'-11110' (seven intervals) NOV ~j 7 true vertical 8842'-9086' (seven intervals) ~ 0il & Gas Cm~, 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch "~[~nl~g Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Bob Kaluza, 564-5344 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby //~/~ ~ certify tl~t the foregoing/i~ true and correct to the best of my knowledge Signed ~~,.[ ~ ~ James Sm Title Senior Drilling Engineer, Acting Date , Commission Use Only Permit Number I APl Number I Appr°val Date ISee cover letter ~',~-,~./~;~' 50- ~¢~2. ¢-' ~--O ~'z~'.2-.." d~ I // -~/~- ¢~7 for other requirements Conditions of Approval: Samples Required []Yes J~ No Mud Log Required []Yes J~ No Hydrogen Sulfide Measures ~lYes []No Directional Survey Required [~'Yes []No Required Working Pressure for BOPE []2M; []3M; ~[5M; [-I10M; [--115M Other: Original ~' Approved By David W .Inhneh;~ Commissioner the commission Form 10-401 Rev. 12-01-85 Submit In Triplicate ]Well Name: I 13-06A Well Plan Summary I Type of Well (producer or injector): I hajector RECE VE ?~0¥ i 7 19~ g/aska Oil & i~as Cons, Commission Anchorage Surface Location: 1643'FSL, 5199'FEL, Sec. 13, T10N, R14E X = 687304.04, Y = 5,931712.29 Target Location: 1903' FSL, 1335' FEL, Sec. 13, T10N, R14E Top of Core Point X = 691,160.00 Y = 5,932,070.00 Z=8,703'TVDss Injection Location 1948' FSL, 1307' WEL, Sec. 13, T10N, R14E X = 691186.93 Y = 5932115.73 Bottom Hole Location: 1963' FSL, 1298' FEL, Sec. 13, T10N, R14E X = 691195.43, Y = 5,932,130.17, Z=I 1,019'TVDss AFE Number: 14J0378 (Core)& 1 4J0377 (Drill) I Estimated Start Date: I 12/1/97 Rig: I Doyon #141 I Operating days to complete: 124 I mI>: 1~,2oo' I I TVD: 19,349 I IWell Design (conventional, slim hole, etc.): I g~: 174.00, I Isidetrack ultra slim hole horizontal with a core location. [Objective: [ A core location with wellbore conversion to WAG injector. Formation Markers Formation Tops MD TVD(BKB) Begin sidetrack 7000 5954 Sidetrack from section in 9-5/8"casing in lower Ugnu West Sak 7357 6228 End 6-7°/100 drop 7657 6465 angle dropped to 40.4°, azim. turned to 41° Top Seabee 7713 6508 Top CMl 9347 7752 Top HRZ 10519 8682 Sag River 10682 8841 Start core 10' above the Sag River Shublik 10705 8864 Z4B 10783 8940 Z4A 10923 9078 Zone 3 11019 9173 Will core 30' into Z3 TD 11199 9348 Then drill 150' of rathole to TD Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MDfrVD MDfrVD O.D. existing 13-3/8" 72# L-80 BTC 2660' 30'/30' 2690'/2690' existing 9-5/8" 47# L-80 BTC 10752' 30'/30' 10782'/8852' plugged 7" 29# L-80 8RD 1349' 10443/8584' 11792'/9628' 8-1/2" 7" 27# L-80 Mod 4350' 6850'/6062' 11200'/9353' Liner BTC 7" csg. 4-1/2" 12.6# L-80 BTC 3882' 6700'/5759' 10582'/8743' Tbg. Mod 9 5/8" 5 ½" 17# L-80 BTC 6700' 30'/30' 6700'/5759' csg Tbg. Mod Logging Program: I Open Hole Logs: Core Section: After coring and drilling rathole DPC Log w/Platform Express + Sonic, + Numar (if available). Drilling section: MWD dir from KOP (7000') to bit exhaustion. Add GR to MWD with bit #2 to core point. Sample catchers and rig site geologist from Top of Kingak to TD Mud Program: Special design considerations IDrill to core point with 6% Gel Free Sidetrack Fluid, initial Kick Off mud weight 9.6-9.7 ppg, weight up to 10 ppg prior to Kingak, displace to bland core fluid prior to core depth. Initial Kickoff Mud Properties: 9-5/8" Kickoff in Lower Ugnu Density 10 sec gel Yield Chloride Filtrate ph (PPG) Point s HTHP 9.6-9.7 8-20 45-65 30,000 6.0 API 9.0 Mud Properties after kickoff: I Drilling of Kingak interval Density 10 sec gel Yield Chloride Filtrate ph (PPG) Point s HTHP 10.0 6-15 10-20 30,000 10.0 8.5- 9.0 Reduce yield point to 8-10 prior to displacement to core fluid. 11/25/97 10-46 FA~ 907 $64 $193 BP EXPLORATION ~00~ ~ I Bland Coring Mud i Displaced above Top Sag I Properties: Density I LSYP Yield I Filtrate] ph _(PPG)I _ Point rrHP - 10.0 I 5-8 15-25 <7.5 @200° 7.5-8.5 Do not add any surfactants, lubricants, dlspersant.s, lignites, defoamers, consult with Drilling, Coring and Geology prior to any variance from the planned mud program. Mo6ify the Coring Mud with shale inhibitors (Barotrol) and treat with Baranex to drill the rat hole. The system will need to be pre-treated with Bicarbonate of Soda and thinners in preparation for cementing operations. Directional: KoP: 1)~000'MD, drill out of a 45-50' section in 9-5/8", drop and mm at 7°/100' to 40~ inclination at 40° azimuth, hold tangent for +__ 3,000', then drop and mm at 7°/100'to 10° inclination and 32° azimuth for coring section. Core 360' from TSAG to Zone 3 then 150' - '170'of additional rat bole: 10° inclination while drilling core and rat hole. Maximum Hole Angle: 40.4° tangent section to the core point ~Close Approach Well: 13-05 at 10,009' to 10,080' MD Cement Data: Casing]Liner Lead: Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments P&A of origin~l well 137/15.8/1.15 "G" at 15'.8 ppg Kickoff plug 144)'{7.0/0.997 "0" at 17.0 ppg 7" Liner from 6,800' 270/13.0/2.03 '224/15.7/1.19 '-Class "G", 50% of to 11,209'MD lead excess on open bole, 30% of tail. , RECEiVeD Alaska 0ti & Gas Cons. Commission Anchorage Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and drilling fluid system schematics on file with AOGCC. NO ANNULAR INJECTION IN THIS WELL. Bottom hole pressure is 3,367 psi at 8,800' TVDss (estimated) Maximum shut-in casing pressure is 2,487 psi (assumes 0.1 psi/ft gas gradient to surface). Contacts Name Office Home Pager Bob Kaluza David Nims Toby Archuleta Allison Downey Tim Burns Jake Rathwell Drilling Eng. Drilling Supt. Geologist Pad Engr. Asset Drilling Eng. Lead Core Spec. 564-5344 564-5219 265-6389 263 4299 564 4315 509 6382 563 9059 275-1014 348 2533 275-4539 DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There are no wells which need to be shut in during the rig move. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move. DRILLING CLOSE APPROACH WELL SHUT-INS None identified on Sperry Sun directional well plans. H_~S DS 13 has had H~S reported: The highest levels of H2S from currently producing wells is 122 ppm from 13-05 measured on 10-17-95. Four other wells on DS 13 have reported H2S of _<36 ppm. H2S precautions will be in effect at all times. These include (but are not limited to): · Regular H2S drills (minimum of two per week) · Proper training of all permanent onsite personnel, unescorted visitors and temporary onsite personnel; · H2S monitors with both audible and visual alarms; · Access to 5-minute emergency escape air packs; · Personal H~S monitors; ~E~IV~ · Functional wind indicator; · Posted evacuation routes (minimum of two); NOV '~ 7 i~j[j~. · Muster points in designated safe areas;__H_~SS; · Functional communications between rig camp and rig fl~ 0il & Gas Cons, CorF~to~ Anchorage PORE PRESSURE: The pore pressure in the Kingak is expected to be near 9.6ppg EMW, due to shale instability problems mud weight of 10.0 ppg will be used to drill the Kingak interval. The expected pore pressure in the reservoir is 3367 psi at 8800'TVDss (7.4 ppg EMW).. The planned mud weight of 10.0 ppg during coring and 9.6 - 9.7 ppg in the kick-off section will provide sufficient overbalance to the reservoir pressure. HOLE PROBLEMS DS 13 usually has no unexpected problems in surface hole sections. In intermediate sections there can be Cretaceous Overpressure due to produced water injection. Mud weights of > 9.6 ppg will overbalance any overpressures without causing lost circulation. This well will Kick-off in the lower Ugnu with the drilling fluid weighing 9.6 ppg. Tight hole and bridging problems have occurred in the lower Seabee formation and in the Kingak shale. The drilling fluid will be conditioned to counteract these types of hole problems through the Seabee and Kingak formations. This well will also be using 'bland' coring mud for up to 8 days below an open Kingak formation. While drilling into and through the Kingak the mud will be conditioned with all available shale inhibiting additives to stabilize the Kingak before displacing to 'bland' coring mud. All rig and core personnel are fully aware of potential problems with having long term open hole in the Kingak shale. There has been problems with lost circulation in Zone 4 because the of numerous faults in the formation. Lost circulation, if it occurs, will be handled, quickly and effectively using a comprehensive lost circulation decision tree. No other hole problems are expected in the production/injection zones. Surface Casing Shoe Kick Tolerance The smallest kick tolerance for the kick off window is calculated as 20.4 bbls of influx assuming a swabbed gas influx at the top of the Sag River along the planned directional path. Based on 10.0 ppg MW (Sag at 10,682' MD & 8,841' TVD 9.6 ppg reservoir pore pressure), and a 12.5 ppg window test. 11/25/97 12:01. FAX 907 564 5193 BP EXPLORATION Pre-Rig Work: SUMMARY PROCEDURE RU slickline and drift 5 'fi" tbg.. If cannot get to production packer, notify Operations Drilling Engineer (ODE). Perform CMIT on tbg. IA/OA. Report these results ASAP to the ODE. . P & A open perforations. Open perforations at 10,938-10,948', 10,962-10,992', 11,004-11,024', 11,036-11,046', 11,046-11,056' MD. Perform P&A to 100' below bottom perforation interval, bullhead 28 bbl (137 sx) 15.8 ppg, 1.15 ft3/sx, Class 'G', cement displaced by 239 bbl of seawater. Cement top MUST NOT be above 10,320' MD (minimum per AOGCC = 10,838' or 100' above uppermost open perforations). Tag and test cement plugback. 4. RU electric line and make a chemical tubing cut in the first full joint above production packer (cut at + 10,320' MD). Circulate well to seawater through the cut. Freeze protect to + 2,200' MD. 5. Pressure test the 9 5/8" packoff. Carefully cycle LDS. 6. Set a BPV in preparation of the rig sidetrack. Rig Work:. 1. MIRU. If a plug is set in the well, test plug before ND tree. ND tree. Set BOP blanking plug and NU BOP's. Test same. Pull BOP blanking plug and plug (if set). Circulate well with 8.5 ppg seawater 100%. 2. MU Baker 5 V~" tandem grapple Spear (do not exceed 270K over pull on the tbg. When pulling the hanger/cut tubing free), Pull tubing hanger to rig floor. 3. POOH and lay down the 5 ¥2" production tbg.. Tbg. was cut at @ 10,320' MD. 4. MU Baker 9 5/8" N-1 Cast Iron Permanent Bridgeplug and GR/CCL on electric line. Set plug at + 7,150' MD, log w/GR/CCL from plug setting depth to + 6,700' (need to locate collars for milling). 5. Shut in well and test casing to 2500 psi for 30 minutes against the Bridgeplug to insure casing integrity. If casing leaks PU a RTTS for 9 5/8" 47# and identify the leak point. 6. PU Gray 9 5/8" pack-off running tool, change out 9 5/8" pack-off. Rrm tool to upper pack-off, turn to the right, J-in, back-out set screws in casing spool and back-out alignment pin for lower pack-off. Pull upper pack-off. Run in with running tool, back-out lower pack-off set screws, pull lower pack- off. Install new 9 5/8" lower and upper packoffs. (replacement packoffs in ARCO warehouse). 11 h~; ~.~ ? 7~ !i '~; ;?' i;~ 11/25/97 12:02 FAX 907 564 5193 BP EXPLORATION ~ uu~ 7. Make up Smith Int'l section mill assy.(as per RP). RIH SLM to PBTD. Change out the seawater in the hole to Baroid Milling mud. 8. Spot a 18 ppg balanced mud pill from PBTD to + 7,000' MD. Pull up to _+ 6,950', space out to start milling (milling should start 10' above the nearest collar; correlate using collar locator log). Mill a 45-50' section. See a~ttached milling RP. Try not to pick-up or lay down drillpipe out of the string and number the stands on the rack carefully. If you need to trip for new cutters, by using the same, well marked pipe on the pipe rack you will get back exactly to the cut, also break circulation twice while RIH to clean tooI and hole. Sweep and clean the hole thoroughly before POOH. 9. RIH open ended with + 500' of 3 Vz" tubing stinger and spot a kick-off plug from 100' below the base of the section + 7,100' MD to 200' above the top of the section + 6,750'. See Cement Kick-off Plug Procedure. Pull 12 stands, shut-in and perform hesitation squeeze. Attempt to achieve a 1000- 2000 psi squeeze but do not displace TOC closer than within 100' of the section top at _+ 6,950' MD. POOH, flush BOP stack (do not open doors). Test BOPE. 10. PU ATJ-PS05D 8 ¥2" drill out bit and Sperry Sun assembly, dress the cmt. plug to 5' below the top of the window + 6,955' MD, circulate and condition mud for drilling. Make every effort to drill out of the section smoothly where the build angle does not exceed 7°/100, (90' core barrels need to easily pass through the window). 11. Directionally drill MWD (PU GR with BHA #2) to +100' above TSAG + 10,690' (core point, to be picked by rig site geologist). Circ. & Clean hole. POOH into the KO window. Note: the mud needs be conditioned with the full compliment of shale stabilization additives before and while drilling the Kingak because the hole will be open for up to 8 days using 'bland mud' while coring below the section. 12. Clean pits, mud lines, pumps thoroughly to take on 10.0 ppg 'bland' core mud. Run back to bottom, pump a 75 bbl lo-vis sweep followed by a 75 bbl hi-vis spacer, followed by core mud. Displace well to core mud. See Baroid Recommended Mud Program... Monitor for lost returns. Drill ahead to core point. Circ & clean hole. POOH SLM. 13. MU Baker Inteq coring assembly, Follow coring program. Core 360' from 10' above TSAG to Zone 3. All core for this well must be cut as rapidly as possible to prevent core invasion and reduce Kingak shale exposure time; run 90' barrels whenever possible. Adjustment to the coring plan will be made based on rigsite evaluation i.e. Kingak shale exposure time, core batxel length, core ROP, etc., and after consultation with SSD staff. A PBL sub will be run above the core barrel or motor on every core mn. Circulate and clean hole through the PBL before pulling out of hole each trip. Trip in and out of the hole as per required trip speeds. 12 · I1/25/97 10:46 FAX 907 564 $193 BP EXPLORATION 14. POOH. Lay down coring equipment. PU a RR 8 ¥~" insert bit, MWD/dix assy. RIH to core TD (wash and ream through any tight spots) Cixc. and Condition mud (condition mud to inhibit the Kingak shale) to drill rat hole. Drill 150'- 170' of tat hole (rat hole length determined by amount of fill after tripping). MWD directional will need to be nm with this B HA to survey the coted section as per AOGCC requirements. Cire 8: con& at TD. POOH. 15. Rig up electric linc for open hole logs, RIH Platform Express plus Sonic plus Numar as per geologist request. 16. RIH with 8 1W' drilling assembly to TD. Clean & condition hole for running 7" casing. 17. Run and cement 7", 27#, L-80 liner (with 3 W' inner string for cementing). Space the liner hanger/packer I50' above the 9 5/8" window. Cement the liner in place with the total lead cement volume based on 50 % excess in the openhole, 150' liner lap and 200' above the liner with drillpipe in the hole. Tail cement volume based on 30 % excess in the open hole to ffllup the 8 x 7" annulus to 1000' above the Sag River plus 80' shoe joint. Displace with seawater. See inner string cementing procedure, attached. Bump plug and set liner hanger and packer. Unsting running tool and circulate excess cement from the wellbore the long way. Circulate the well to filtered seawater. POOH. 19. Test liner and liner lap to 3500 psi for 30 minutes. Note: Perforating will be done post-rig. 20. RIH with 5 V2" x 4 V2" L-80 completion with SSSV and 7' x 4 W' packer With standard EOA tailpipe assy with 'X' nipple (will be doing CT work to the lower zones in the future). Circulate corrosion treated seawater into the annulus. Set packer and test robing to 4000 psi for 30 minutes. Bleed off tubing pressure to 2000 psi after test, pressure up annulus t.o 3500 psi for 30 minute test. 21. Set BPV and test. ND BOPE. NU tubing head adapter and tree. Test tree to 5000 psi.. Pull BPV. 22. Release rig. RECEIVED 2 5 filaska 0ii & Gas Cons. Commission Anchorage mp=r-r,u- un wo 4 DrillQuest' DRILLIN[~ i Proposal Oa~ for 13~6a Wp4 Ve~i~ O~in: Well Ho~o~I ~in; Well Me~um~ Un~: Nodh Refer~: Tree No~ ~1~ Sev~: D~ ~ 1~ Ve~ S~n ~m~: 43.430' Measured Incl, ~1~ Venial No~hlngs ~ngs Ve~l D~leg ~pth Depth ~lon ~te 7~,~ 43.751 111.224 5954.23 1195.86 S 22~.81 E 711.22 7030.~ 43.781 108.622 5~5.~ 12~.~ S 2317.32 E 719.50 6.~ 7656.93 40.414 41.034 ~5.03 1114.52S 2673.87 E 1028.82 7.~ 10180.38 40.414 41.0~ 8386,34 119.53 N 3747.89 E 2~3.36 0.~ 1~17.16 10.~ 31.918 8777.~ 261.91N 3863.65 E 2~.34 7.~ 11020.29 10.~ 31.918 9174.~ 321.33 N 3~.~ E 2914.93 0.~ i ~ : SURFACE L~ATION REFERENCE PLOT DATE: 7 - NOV - ~997 - ~ Her zonal C~rdlnates: 5931712.29 N ~7304.04E Created By: - ~ RKB Elevation: 29.50 fi' Rig (EST) - ~-~ ~ 7~ "~P ~.50 ff Well (CBE~ 6000 -- ~'~' nu 74.00ff RKB-AM~L CheckedBy: no - ~ C~rdinate System: NAD27 Nas~ S~te Plan~, ' ~ ~72~.~ ~ne 4, US Foot - ~ ~ ProposaITarget Summa~ . 6600 -- X X I3.AT-- 8~3.. 8~,. 261.91 ~ 3863.65 E 5~2070.. N, 6911... E oo; .... X - 261.91 N, 3863.65 E 5 ::::::: :::::::::::::::::::::::: 9000 ~ ...................................................................................................... ~' ............................ ................................................................................................. ::::::::::::::::::::: - 7" Lin~ - 11020.29 ~, 9174.~ ~ _ 9600 -- 6~ 1200 1800 2400 3000 Scale: 1 inch = 600~ Vedical Section Section Azimuth: 43.430 (Tree No~h) nRILLING c~ I= RV I r' E c; 13-06A Wp 4 DrillQuesf SURFACE LOCATION REFERENCE I PLOT DATE: 7 - NOV - 1997 Horizontal Coordinates: 5931712.29 N 687304.04E Created By: RKB Elevation: 29.50 fY Rig (EST) 44.50 ff Well (CBE) 74.00, RKB- AMSLI Checked By: bp Coordinate System: NAD27 Alaska State Planes, Zone 4, US Foot I Proposal Data for 13-06a Wp4 Ver~cal Origin: Well Measurement Orits: Noflh Re~emnca: True North Dogleg Severity: Degrees per lOOft Ver'~aJ Sec~:~ AzJmu~: 114.996' M~a~tn'ed }n~L Azlm. VerticalNorthtnge Ea~tlnge Vertical Doglee R~'-- 70OO.OO43.'/51 111.2245954.23 1195.g6 S 2297.81 E 2587.91 T030.O043,781 108.6225975.9O 1202.93 S 2317.32 E 26O8.576.OOO 7656.9340,414 41.O34 6465.03 1114.52S 2673JV/E2894.377,000 101g0.38 40,414 41,034 8396.34 119.53 N 3747.89 1~ 3346.330,000 10617.16 10.OOO 31,918 8777.OO 261.91 N 3963.65 E 3391.097,000 11O2O.29 IO.OOO 31,918 9174.00 32133N 3900.66 E 3399.52O.OCO Proposal Target Summary Targe~ Name:TVD.~: TVDrkb: WellbeM Offse~: Global C_.oo~lia~e~: 13-06A Tazg~8703.00 8777.00 261.91 N, 3863.65 E 5932070.00 N, 691160.CO E Eastings Scale: linch = 600ft 1200 1800 2400 3000 3600 4200 [ I I I [ I I I I [ [ [ I I I I I I I [ [ I ~ [ I I I I ~ I I I I [ I I ~ I I I I [ I I I I I I I [ [ I -1200 -- -- -- -- -- -- 7106.93 6726.24 7" Liner - 11020.29 MD, 91 13-06A TI 8777.00 TVD 261.91 N, 3863.65 E 1200 1800 Scale: linch = 600ft Reference is Tree North 2400 3000 7487.62 Eastings 3600 4200 600 ~1/12/1997 i 5: 33 9875637252 SPERRY-SU~ Sperry-Sun Drilling S iCes. Proposal Report for '13-06A - "13-06e Wp5 PAGE 85/85 Shared Services Drilling North Slope Measur~cl (fl) Incl. 7000,00 43,7,51 111,224 70'~0.00 43,781 10~.622 7656.93 40.414 41.034 10180.38 40,414 41,034 10617.16 10,000 31,918 11020.29 10,000 31.918 Vertical (n) 6465.0:3 8386.34 9174.00 Northlnga (~) 11G5.~ 8 1202.93 S 1114,52 8 119.53 N 261.91 N E~tlngl (fi:) 2297.81 2317.a2 2673.87 37a.7.89 ~.~ AK State Plane Zone4 PBU_EOA DS 13 Vertical Deeleg · ~4GtJon Rate (f~) (-/~ooft) 2191 2210.73 6.000 2573.3~ 3745.05 0.0G0 3872.11 7.000 3900.66 IE 3913.87 All data is in feet unless otherwise stated. Directions and coorclinataa are relative to True North. Vertical depths are relative to Well. Northlngs and Eastings ere relative to Well, The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 85,291°'(True), Based upon Minimum Curvature type calculations, at a Measured Depth of 11020,28ft,, The Bottom Hole Displacement is 3913.87ft., in the Oirectlorl of 85,291 ° (True). Forrnaflon Tops Measured Vertical Sub-Sea Depth Depth Depth (~t) (fl) (fl) 7356,79 6228,00 6154,00 7713,37 6508.00 ~434.00 9;347,24 7752.00 7678.00 ' 10519.4,6 ~682,00 10~2.15 ~841,00 8767 10705.51 8864.00 8790.00 10782.08 8~40,00 8866.00 10922.81 9078.00 9004,00 1101g.27 9173,00 9099.00 Casing details From Measured Vertle. al Depth Depth (ft) <Surf'aM> <,~urface> Northlngs 1213.02 287.90 243.40 271,49 274.94 N 286.31 N 306.9~ N 321,18 N TO Measured Ve/IJ(:al [;)ap'ch Depth (~) 11020.29 g174.00 252t.56 £ 3393.2'9 E 385O.73 G. 3871.75 E 3878.84 E 3891.71 G 3900,S7 E Caain~ De~II 7' Liner PorrrmtlQn Name Wamt To~ ~ CMl THRZ · ~ag River ~hublik ZaB ZAA Z3 12 Novernbe~, 1997 - ~ 1:47 .1. OrlllQue,~t Sperry. Sun Drilling Services Proposal Report for 13.06A. 13-06a Wp$ Shared Services Drilling North Stope Ind. Aztm, Vertical Local Coo~inates Dq~ Northin~ Easfl~s 7000.00 43.751 111.224 ,51}80.23 595423 7030.00 43.781 106.622 5901.90 5975.90 7100.00 41.492 102.222 ~)953.41 6027.41 7200.00 38.907 92.131 6029.87 6~03,87 7300.00 37.280 81,083 6106.66 6t82,66 7356.79 36.835 14.525 G134.00 G~2:6.00 7400.00 :3G.742 00.476 Gt88.G1 0202,61 750Q,00 37.340 57.885 G268.53 G342.53 7GO0.OO 39.022 4G.879 G347.23 G421.23 7656.913 40,414 4t .034 G395.03 G4G6.93 7706,00 40.414 41,034 G423.82 G497,82 77t3.37 40.414 41.034 6434.00 6506.00 7800.00 40.414 41.03~ 6499.96 6573.96 7900.00 40.414 41.634 6576.t0 6(XX),00 40.414 41.034 66~2.24 67'262.4 6100.00 40.414 4t.034 6728.36 6802.38 6200.00 40.414 41,034 6804.51 6878.51 ~300,00 40.414 4t.0N 6680,65 6064.65 8400.00 40.414 41.034 6956.79 7030.79 1~500.00 40,414 41.034 7032.93 7106.93 6600.00 40.414 41.034 7106.07 7183.O7 6700.00 40.4.14 41.034 71~.20 725920 0800,00 40.414 41.034 7261.34 7335.34 8,900.00 40.414 41,034 7337.48 7411.45 96(X).00 40.414 41,034 7413.62 7487,62 1195.86 S 2297.81 E 120zgGs 2317.32E 1215,58 S 2362.96E 1223.77 S 2426.79 E 1220.23 $ 2486.17 E 1213.02 S 2521.50E 1205,03 S 2546.17 E 1178,39 S 2599.94 E 1140.70 S 2648,66 E 1114.52S 2673.67 E 1093,46 S 2692,20 E 1086.~ S 2697.69 E 1044.56 S 2734,76 E ~95,65 S 2777.32 E 946,75 S 2819.~8 E 897.65 S 2862.45 E 848.94 S 290~01 E ~0,04 S 2947,57 E 751.14 S 29~.13 E 70223 S 3032.69 E 653,33 S 3075.25 E 604,43 S 3117,82 E 555,52 S 3100.38 E 506.62 S 32O2.94 E 457.72 $ 3245.50 E Global Ho~ Ref Dogleg Vertlcd Nc#~lngs Eastings Ra~ Saclkm (fl) (I) ('ll00fl) (fi) 5630573,82 Id 680630.82 E 711.22 593066724 N 68965Q.49 E 6.000 716,50 5930656,73 Iq 689606.43 E 7.000 741.69 5630549.12 N 689760.45 E 7.000 Tr9.62 ,5030554.17 N 669621.72 E 7.000 824.38 69305G2.,21 N 6~}654.94 E 7.000 852.50 5930570.81 N 689679.33 E 7.000 675.30 58;~508.78 FI 680932.42 E 7.000 9~1.6t 5630637.6614 689960. t9 E 7,000 992.47 5930664.46 N 690004.74 E 7.000 1028.82 593068~.97 N 600022.54 E 0.O0O 1056.71 5630602.65 N 696028.07 E 0.000 1065.37 5030735.~ N 690063J~ E 0.068 1121,49 5930785.86N 690105.21 E 0.000 1t86.26 5930835.61 N 690t46.55 E 0.000 1251.04 56:]0655.75 N 60Ot87.88 E 0.000 1315.8t 503003~70 rd 6g0229.22 E 0.600 1380,5~ 5936985,6414 690270.5~ E 6.600 1445.36 5031035.58 N 690511.~9 E 0.000 15t0.13 5931085.53 N 690353.22 E 0.000 1574.61 5031135.47 N G~}394.58 E 0.000 1639.68 56311~5.42 N 690435.89 E 0.000 1704.45 5931235.36 N 690477.23 £ 0.000 1769.23 5931286.31 N 690516.56 E 0.000 1834.00 5631335.251d 690550.~ E 0.600 1868.78 Top ,Settee AK State Plane Zone4 PBU_EOA DS 13 f2 November, f997-1'~:48 - 1 - DrillQuest Sperry-Sun Drilling Services Proposal Report f~r 13.06A. f3-06a Wp$ Shared Services Drilling North Slope M~asurecl 9100,00 9290,0O 9300,90 9347.24 9400.00 10000.00 10190.00 10180.38 1(12(X).0O t0300.0O 10400,00 10500.0O 10519.46 10600,00 10617,16 40.414 40.414 40.414 40.414 40.414 40.414 40.414 40,414 40.414 40.4t4 40.414 40,414 40,414 39.043 ~2,056 25.O75 18.108 16.755 ! 1.179 Sub.Sea V~rlical Local Coordlnabm Baplb I~orthi~ Eastings (n) (lq m) 41.034 7489,15 7563.75 408,8t S 3288.90 E 41.034 7565.89 7639.89 359,9~ S 3,330.62 E 41.034 764Z03 7716.03 311.01 S 3373,18 E 41.0DI 7678.90 7752,90 287.90 S 339329 E 41,034 7718.17 7792.17 262.10 S 3415.75 E 41.034 7704.31 7868.31 213.20 S 3458.:31 E 41.034 7870.44 7944,44 164.30 $ 3500,87 E 41,034 7946.58 8020.58 ! 15,~ S 3543,43 E 41.034 8022.72 8096.72 66.49 S 3585.90 E 41.034 809&88 8t72.86 17.50 S 3628.55 E 41.034 8175.00 6249.00 31.32 N 3671.12 E 41.034 8251.13 8325.13 80,22 N 3713.68 E 41,034 8312,34 8386.34 119.53 N 3747.89 E 40.916 8327.42 8401.42 129.00 N :]756.11 E 40.183 8408.73 8482.73 173.12 N 3793.91 E 39.095 8496.5t 8510.51 209,89 N 3824.43 E 37,236 8589.43 8663,43 238,74 N 3847.23 E 36.703 8608.00 8682.00 243.40 N 3850,73 E 33.169 8686.13 8760.13 259.26N 3861,95 E 3t.918 8703,0O 87Z7.90 261.9t N 3863.65 E 10682,15 10.000 31.918 8767.00 8841 10706.00 10.000 3t.918 6784.58 8858.58 10705,51 I0,000 31.918 8790,00 8864,90 10782,6B 10.006 31,918 8866.00 8940,90 1080O,00 10.000 ~t.918 8883.06 6957.06 271.49 N 3660.62 E 274.12 N 387125 E 274,94 N 3671,76 E 286.31 N 3678.84 E 288.86 FI 3880.44 E Global Horz, Ref IN)01eg Vertical NerthaW~ Em, Umpi Section (iii (lq t',oeftl (Itl 59~13~5.20 N ~04~001.23 E 0.0iX) 1963.55 5931435.14 N 6~i642.57 E O.0O0 2028.32 6931485.06 N 690683.90 E 0.00O 2093,10 5931506.68N 690703.43 E 0.00O 2123.70 56(31535.03 N 690725,24 E 0.00O 2t57.87 5931584.97 N 600766.57 E 0.O0O 5931634.92 N 690607.91 E 0.000 2287.42 5631684.86N 690849,24 E 0,000 2352.19 5931734.81 N 690890,58 E 0.00O 24t6.97 5931784.75 N 660931.91 E 0,000 2481.74 5931834.70 N 690973.25 E 0.000 2546.52 5931884,64 N 691014.58 E 0.090 26t,1~9 50131924.791'4 664047.81 E 0,00O 2663.36 5931934.45 N 691055.79 E 7.0O0 2675,88 5931979.51 N 691092.48 E 7.090 2733,92 5932017.02 N 69112?.09 E 7.00O 278t.60 5932046.43 N 661144.16 E 7.000 2818~2 5932651.17 N 601147.55 E ?.0OO 2824.02 5932067.30 N 691158.37 E 7.000 2843.24 5932070.00 N 691160.00 E 7.000 2846,34 5932079,72 N 691165.73 E 0.000 2857.40 5932082.39 N 6~1167.30 E 0,(XX) 2860.44 5932083.22 N 691167.78 E 0.030 2861.37 5932094,77 N 691174.59 E O.O00 2874,50 5932097,36 N 691176,11 E 0.000 2677,45 CMl Shub~k Z4B AK Slate Plane Zone4 PBU_EOA DS 13 Cont/'noec[... 12 November, 1997-1f:48 -2- Dn'//Ouest Sperry-Sun Drilling Services Proposal Report for f 3-O6A . 13.06a Wp5 Shared Services Drilling North Slope G~ How. R.f Dogi.g Verfful Northin~ Ea~n~ P.~ Sedlo~ ~ ~) (',~q (~) 10~0,00 10.O00 $1,918 8981.54 9055.54 303.60 N 3889.62 E 10922.81 10.000 31.918 9004.00 9078.00 306.96 N 3891.7t E 11000.00 t0.000 31.918 9080.02 9154.(]2 318,34 N 3898.80E 11019.27 10,000 $1.918 9099.00 9173.00 321,18 N 3900.51 E 11020.29 10.000 ~1.9t8 9100.00 9174.00 321.33 N 3900.66 E 5932112.32 N 681184.92E 0.000 2894.47 5932115,73 N 691186,93 E 0.000 2898,35 5932127.26 N 681193.74 E 0.00O 2911A8 5~2130.17 N 681195.43 E 0.000 2914,76 5932136.32 N 691196.52 E 0.000 2914.93 All data is in feet unless otherwise stated. Directions and coordinates are relative (o True Nm'th. Verlical depths are relative to Well. Norlhings and Eastings are relative to Well. Based upon Minimum Curvature lype calculations, at a Measured D~th of 11020.29fL, The Bottom Hole DispLacement is 3913.871t,, in Ihe Direction of 85.291 ° (True). Ce~mmnt Z4A Z3 7' Liner AK State Plane Zone4 PBU...EOA DS 13 12 NovemGe~, 1997- ~ f : 48 - 3. DrigQues! 11/25/97 10'45 FAX 907 564 5193 BP EXPLORATION SURJ ECT BP EXPLORATION ENGINEERING DATA ,..qH EET NO. OF BASED ON ENGINEER DEPT. APP'VL_ DATI=__ BUDGET/AFl= NO FILE NO_ AK 2337-I (3194) ~OV 25 199~ A~k~ Ot~ & ~ Oons. ~omm~rmlo~ Anchorage 11/25/97 12:01 VAX 907 564 5193 kip EXPLONA'I'ION L~.UUJ_ BP EXPLORATION SUBJECT BASED ON ENGINEER ,~"~'~"~'~":~ ENGINEERING DATA SHEET NO. OF DEPT. APP'VL. DATE ,_ 'BUDG ETIAFE NO. FILE NO. AK 2337-1 (3194) 09/22,97 I 001279411 . VENDOR ALASKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 092297 CKO92297F 100. O0 lO0. O0 HANDLING INST' s/h teeei hubble x 4528 'W; AI'rA~HFO ~HF(~K Iff IN PAYMENT FOR ['rEMS DESCRIBED ABOVE. ~-I[~'~l~l~ -- .. ~.~ ,..,. ,., ,.~ ..... · WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS ,/- GEOL AREA ~'?<~::> UNIT# "./,./~",¢~.,~ ON/OFF SHORE :ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DA'gE 14. Conductor string provided ................... Y 15. Surface casing protects all known USDWs ........... Y 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17. CMT vol adequate to tie-in long string to surf csg ........ Y 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. ---- 21. If a re-drill, has a 10-403 for abandonment been approved... ('~.,,N 22. Adequate wellbore separation proposed ............. ~N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation .......... N 26. BOPE press rating appropriate; test to ~ psigl N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N REMARKS GEOLOGY A~PPR D,~TE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y~Y N ./." ,/,,~,,,,2~ 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. N 34. Contact name/phone for we.ekly,progreSSlexploratory only]rep°'rts ...... .// Y N GEOLOGY: ENGINEERING: COMMISSION: JDH ~ RNC~ co ~o'1~ Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Jan 29 16:21:21 1998 Reel Header Service name ............. LISTPE Date ..................... 98/01/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/01/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 3 AK-MW-80047 E. CRIBBS D. BURLEY ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 13-06A PB1 500292064270 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 29-JAN-98 13 i0N 14E 1643 5122 73.60 72.10 44.50 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 13.375 2660.0 9.625 6974.0 10628.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS I AND 2 ARE DIRECTIONAL ONLY, AND ARE NOT PRESENTED. 3. MWD RUN 3 WAS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS NOT POSSIBLE: WELL 13-06A PB1 HAS NO MWD GAMMA RAY DATA AT THE KICKOFF POINT FROM 13-06 WELLBORE, OR ABOVE. 5. MWD RUNS 1 THROUGH 3 REPRESENT WELL 13-06A PB1 WITH API#: 50-029-20642-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10268'MD, 8781'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # - FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9119.0 10555.5 ROP 9192.5 10628.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 9191.0 10628.0 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9119 10628 9873.5 3019 9119 ROP 5.7878 901.758 87.794 2872 9192.5 GR 57.1758 370.312 146.301 2874 9119 Last Reading 10628 10628 10555.5 First Reading For Entire File .......... 9119 Last Reading For Entire File ........... 10628 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH GR 9119.0 ROP 9192.5 $ 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 INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10555.5 10628.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 20-DEC-97 5.07 PCD 2.01 / PCG 6.90 MEMORY 10628.0 9191.0 10628.0 12.5 44.2 TOOL NUMBER PCG 67 8.500 8.5 GLYCOL ENHANCED 10.00 44.0 8.0 30000 4.6 .000 .000 .00~ .000 67.8 .6 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9119 10628 9873.5 3019 9119 ROP 5.7878 901.758 87.794 2872 9192.5 GR 57.1758 370.312 146.301 2874 9119 Last Reading 10628 10628 10555.5 First Reading For Entire File .......... 9119 Last Reading For Entire File ........... 10628 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/01/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/01/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Fri Jan 30 16:18:04 1998 Reel Header Service name ............. LISTPE Date ..................... 98/01/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/01/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: Oate~ I ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 13-06A 500292064201 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 30-JAN-98 MWD RUN 4 MWD RUN 5 MWD RUN 6 AK-MW-80047 AK-MW-80047 AK-MW-80047 E. CRIBBS J. PANTER R, KRELL D. BURLEY B. OWENS B. OWENS 13 I0N 14E 1643 5122 73.60 72.10 44.50 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2660.0 9.625 6974.0 8.500 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 3 REPEPRENTS THE PLUGGED-BACK 13-06A PB1 WELLBORE. 4. MWD RUNS 4 THROUGH 6 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. 5. MWD RUNS 7, 8 ARE ROP ONLY (CORING). SPERRY-SUN WAS RELEASED PRIOR TO THE WELL REACHING TOTAL DEPTH (TD). NO DEPTH SHIFTING/CORECTION OF MWD DATA IS POSSIBLE: THERE IS NO MWD GAMMA RAY DATA IN OR ABOVE THE KICKOFF POINT FROM THE 13-06 WELLBORE. 6. MWD RUNS 1, 2 AND 4-8 REPRESENT WELL 13-06A WITH API#: 50-029-20642-01. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Nunlber ........... 1.0.0 Date of Generation ....... 98/01/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD o Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUM>fARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8442.0 10455.0 ROP 8507.0 10519.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE MWD MWD MWD $ REMARKS: 4 8507.0 8564.0 5 8564.0 10099.0 6 10099.0 10520.0 MERGED MAIN PASS, $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8442 10519.5 9480.75 4156 8442 ROP 3.9415 2151.56 58.5103 4026 8507 GR 49.7352 319.5 116.958 4027 8442 Last Reading 10519.5 10519.5 10455 First Reading For Entire File .......... 8442 Last Reading For Entire File ........... 10519.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8442 . 0 8498 . 0 ROP 8507 . 0 8563.0 $ LOG HEADER DATA DATE LOGGED: 25-DEC-97 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 INCLINATION (DEG MINIMUM ANGLE: 39.3 MAXIMUM ANGLE: 39.3 5.07 PCD 2.01 / PCG 6.90 MEMORY 8564.0 8507.0 8564.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAM/V~ PROBE $ TOOL NUMBER PCG 61 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL S/TRACK FL 10.10 51.0 11.0 20000- 4.4 .000 .000 .000 .000 44.5 NEUTRON TOOL I~ATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .6 REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8442 8563 8502.5 243 8442 GR 63.3424 126.225 89.038 113 8442 ROP 6.4087 130.311 28.5877 113 8507 Last Reading 8563 8498 8563 First Reading For Entire File .......... 8442 Last Reading For Entire File ........... 8563 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8498.5 ROP 8564.5 $ 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 INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10034.5 10099.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 28-DEC-97 5.07 PCD 2.01 / PCG 6.90 MEMORY 10099.0 8564.0 10099.0 9.3 48.9 TOOL NUMBER PCG 61 8.500 8.5 KCL S/TRACK FL 10.60 53.0 8.9 27500 2.2 .000 .000 .000 .000 61.1 .6 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8498.5 10099.5 9299 3203 8498.5 GR 50.1771 316.878 118.182 3073 8498.5 ROP 3.9415 2151.56 57.5788 3071 8564.5 Last Reading 10099.5 10034.5 10099.5 First Reading For Entire File .......... 8498.5 Last Reading For Entire File ........... 10099.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Con~nent Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10037.0 10455.0 ROP 10101.5 10519.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE 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 INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 30-DEC-97 5.07 PCD 2.01 / PCG 6.90 MEMORY 10520.0 10099.0 10520.0 6.7 9.4 TOOL NUMBER PCG 58 8.500 8.5 KCL S/TRACK FL 10.60 76.0 8.5 24000 3.2 .000 .000 .000 .000 61.1 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 6 AAPI 4 1 68 ROP MWD 6 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 10037 10519.5 10278.2 966 GR 49.7352 319.5 115.733 837 ROP 9.1087 495.888 65.6487 837 First Reading 10037 10037 10101.5 Last Reading 10519.5 10455 10519.5 First Reading For Entire File .......... 10037 Last Reading For Entire File ........... 10519.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/01/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/01/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * . . . ............................ . ....... SCHLUMBERGER ....... . ............................ . COMPANY NAlWiE : ARCO ALASKA INC. WELL NAME : 13-06A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20642-01 REFERENCE NO : 98078 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MA~-1998 12:40 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/03/ 6 ORIGIN : FLIC REEL NAME : 98078 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, 13-06A, PRUDHOE BAY, API #50-029-20642-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/03/ 6 ORIGIN : FLIC TAPE NAME : 98078 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : ARCO ALASKA INC, 13-06A, PRUDHOE BAY, API #50-029-20642-01 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING RUN1 98078 S. Morrison Jim Ray 13-06A 500292064201 ARCO Alaska Inc. SCHLUMBERGER WELL SERVICES 6-MAR-98 RUN 2 RUN 3 1643 5199 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 6980.0 13 iON 14E 73.60 72.10 44.50 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED OPENHOLE DATA ACQUIRED ON ARCO ALASKA'S 13-06A WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SD?4~UL~Y LDWG TOOL CODE AIT SDN CNT BCS $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10951.0 7022.0 10940.0 7002.0 10929.0 7002.0 10908.0 7002.0 BASELINE DEPTH 6894.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED MAIN LOG DATA ACQUIRED IN OPENHOLE ONLY. SPERRY SUN'S MWD GAF~A RAY IS BEING USED AS THE PDC GAMFiA RAY FOR THIS WELL. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... AIT SDN CNT BCS 6876.5 82.5 RUN NO. PASS NO. FiERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 120 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 8 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 TENS BCS LB 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 TEND BCS LB 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 ~IRES BCS 0H~4~1092641 O0 000 O0 0 1 1 1 4 68 0000000000 MTE~BCS DEGF 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CArT PU-S 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CArT CPS 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 DEV SDN DEG 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN 0H~94 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 ~INOR SDN OH~I 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN 0H~4~1092641 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN OH~4 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 AFiO AIT 0H~1092641 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) AF20 AIT OH~M 1092641 AF30 AIT OH~ 1092641 AF60 AIT OPi~ 1092641 AFgO AIT OH~ 1092641 SP AIT MV 1092641 GR MWD GAPI 1092641 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 t 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10960.000 MRES.BCS 0.073 CNTC. CNT -999.250 FCNT, CNT -999.250 DRHO.SDN -999.250 ~NOR.SDN -999.250 AF20,AIT -999.250 SP,AIT -999.250 DEPT. 6870.000 MRES.BCS -999.250 CNTC. CNT -999.250 FCNT, CNT -999.250 DRHO,SDN -999.250 F~VOR,SDN -999.250 AF20,AIT -999.250 SP.AIT -999.250 GR.BCS -999.250 TENS.BCS 7065.000 TEND.BCS MTEM. BCS 170.855 NPHI.CNT -999.250 CPHI.CNT CFTC. CNT -999.250 CRAT. CNT -999.250 NRAT. CNT NCNT. CNT -999.250 DEV. SDN -999.250 DT. BCS PEF. SDN -999.250 RHOB.SDN -999.250 MINV. SDN MSFL. SDN -999.250 CAL1.SDN -999.250 AFiO.AIT AF30.AIT -999.250 AF60.AIT -999.250 AF90.AIT GR.MWD -999.250 GR.BCS -999.250 TENS.BCS -999.250 TEND.BCS MTEM. BCS -999.250 NPHI.CNT -999.250 CPHI. CNT CFTC. CNT -999.250 CRAT. CNT -999.250 19RAT. CNT NCNT. CNT -999.250 DEV. SDN -999.250 DT. BCS PEF. SDN -999.250 RHOB.SDN -999.250 MINV. SDN MSFL.SDN -999.250 CAL1.SDN -999.250 AFiO.AIT AF30.AIT -999.250 AF60.AIT -999.250 AF90.AIT GR.MWD 29.969 1079.525 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~4MARY LDWG TOOL CODE BCS CNT $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 7002.0 6846.0 7002.0 6846.0 BASELINE DEPTH 88888.0 6973.0 6966.0 6963.0 6960.0 6945.5 6944.0 6934.0 6926.0 6914.5 6913.0 6895.0 6894.0 100.0 $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... BCS CNT 88870.0 6955.0 6948.0 6943.5 6940.5 6928.0 6925.5 6915.0 6908.5 6898.0 6896.0 6877.0 6876.5 82.5 THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED MAIN LOG DATA ACQUIRED UP INTO CASING. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUAIB SAMP ELEM CODE (HEX) DEPT FT 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH BCS GAPI 1092641 O0 000 00 0 2 1 1 4 68 0000000000 TENS BCS LB 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 TEND BCS LB 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-S 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU-S 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 1092641 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7002.000 GRCH. BCS 65.663 TENS.BCS 3775.000 TEND.BCS NPHI. CNT 32.728 CPHI.CNT 34.818 CNTC. CNT 1588.839 CFTC. CNT CRAT. CNT 3.035 NRAT. CNT 3.134 FCNT. CNT 476.461 NCNT. CNT 900.345 511.524 1608.345 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: DEPT. 6846. 000 GRCH. BCS NPHI. CNT 34.292 CPHI. CNT CRA T . CNT 3. 035 NRA T. CNT 42.011 TENS.BCS 32.866 CNTC. CNT 3.321 FCNT. CNT 3563. 000 TEND. BCS 1545. 054 CFTC. CNT 504. 294 NCNT. CNT 873.064 515.237 1548.497 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~L~gY FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed b¥ files for other main pass tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10970.0 7020.0 BHC 10926.0 7020.0 PEX 10958.0 7020.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: Il-JAN-98 8C0-609 1130 Il-JAN-98 2115 il-JAN-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ARRAY INDUCTION PEX PLATFORM EXPRESS $ TOOL NI]M~ER ........... SDT-C AIT-H HILTB-DTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FW Dispersed 10.50 66.0 8.6 167.0 0.213 73.0 O. 162 73.0 O. 149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REFL~RKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CNL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW OPENHOLE MAIN LOG DATA SAMPLED AT 0.5'. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUPfl~ SAMP ELE~ CODE (HEX) DEPT FT 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 GR BHC GAPI 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 TENS BHC LB 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 HTENBHC LB 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 ~ES BHC OH~4M1092641 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMBHC DEGF 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 SP AIT MV 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR PEX 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT PEX CPS 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI PEX DEG 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU 1092641 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 10 DEPT. 11004.000 GR.BHC MRES.BHC 0.073 MTEM. BHC CNTC. PEX 2474.804 CFTC. PEX RCFT. PEX 997.879 RCNT. PE~ TNPH. PEX 23.825 NPOR.PEX DEPT. 7020.000 GR.BHC ~4~ES.BHC 0.121 MTEM. BHC CNTC. PEX 1588.839 CFTC. PEX RCFT. PEX 476.461 RCNT. PEX TNPH. PEX 34.818 NPOR.PEX 35 170 1083 2420 23 65 122 511 1608 32 .939 TENS.BHC .855 SP.AIT .815 TNRA.PEX .136 DEVI.PEX .437 .663 TENS.BHC .029 SP.AIT .524 TNRA.PEX .345 DEVI.PEX .917 3325.000 HTEN. BHC -50.188 DT.BHC 2.312 RTNR.PEX -999.250 NPHI.PEX 3775.000 HTEN. BHC 38.563 DT. BHC 3.035 RTNR.PEX 43.533 NPHI.PEX 952.853 88.100 2.431 27.606 900.345 59.000 3.134 32.728 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUNfMARY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10970.0 7020.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 11 BHC PEX $ LOG HEADER DATA 10926.0 10958.0 7020.0 7020.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : il-JAN-98 8C0-609 1130 Il-JAN-98 2115 Il-JAN-98 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ARRAY INDUCTION PEX PLATFORMEXPRESS TOOL NUMBER SDT- C AIT-H HILTB-DTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FW Dispersed 10.50 66.0 8.6 167.0 O. 213 73.0 O. 162 73.0 O. 149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN) '. 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AITand BHC, Bowspring on CNL AITrun Compute Standoff, Eccentered Maximum deviation 48.9 deg LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 12 There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW OPENHOLE MAIN LOG DATA SAMPLED AT O. 25 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUA~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP BL~M CODE (HEX) DEPT FT 1092641 O0 000 O0 0 4 ! 1 4 68 0000000000 AIBD AIT IN 1092641 O0 000 O0 0 4 1 1 4 68 0000000000 AFiO AIT 0P~4~1092641 O0 000 O0 0 4 1 1 4 68 0000000000 AF20 AIT 0H~1092641 O0 000 O0 0 4 1 1 4 68 0000000000 AF30 AIT 0P~4~1092641 O0 000 O0 0 4 1 1 4 68 0000000000 AF60 AIT 0H~4~1092641 O0 000 O0 0 4 1 1 4 68 0000000000 AF90 AIT 0H~4~1092641 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 13 DEPT. 11004.000 AIBD.AIT AF30.AIT 1.722 AF60.AIT 4.301 AFiO.AIT 1.893 AF90.AIT O. 925 AF20.AIT 1.806 1.523 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SD?4~HLgY FILE HEADER FILE NUMBER 5 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10970.0 7020.0 BHC 10926.0 7020.0 PEX 10958.0 7020.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : ll-JAN-98 8C0-609 1130 Il-JAN-98 2115 Il-JAN-98 11094.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 14 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 10976.0 6846.0 10960.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ARRAY INDUCTION PEX PLATFORM EXPRESS $ TOOL NUMBER ........... SD T- C AIT-H HILTB -DTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FW Dispersed 10.50 66.0 8.6 167.0 O. 213 73.0 O. 162 73.0 O. 149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CArL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW OPENHOLE MAIN LOG DATA SAMPLED AT 0.1667'. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 15 * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 $ 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 TT1 BHC US 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 TT2 BHC US 1092641 O0 000 O0 0 $ 1 1 4 68 0000000000 TT3 BHC US 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 TT4 BHC US 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 HDRA PEX G/C3 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 PEFZ PEX 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 RHOZ PEX G/C3 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 PiMIN PEX OH~K4 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 H~fNO PEX OH~ 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 RXOZ PEX 0H~4~1092641 O0 000 O0 0 5 1 1 4 68 0000000000 RX08 PEX OH~q1092641 O0 000 O0 0 5 1 1 4 68 0000000000 HCNT PEX CPS 1092641 O0 000 O0 0 $ 1 1 4 68 0000000000 HCFT PEX CPS 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 HGR PEX GAPI 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 RHFT PEX CPS 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 RHNT PEX CPS 1092641 O0 000 O0 0 $ 1 1 4 68 0000000000 DPHZ PEX PU 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 HTNP PEX PU 1092641 O0 000 O0 0 $ 1 1 4 68 0000000000 HNPO PEX PU 1092641 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR~1998 12:40 PAGE: 16 ** DATA ** DEPT. 11004.000 TT1.BHC 570.400 TT2.BHC TT4.BHC 378.000 HDRA.PEX -999.250 PEFZ.PEX HMIN. PEX 0.129 HMNO.PEX 0.065 RXOZ.PEX HCNT. PEX 2474.804 HCFT. PEX 1083.815 HGR.PEX RHNT. PEX 2420.136 DPHZ.PEX 60721.211 HTNP. PEX 395.200 TT3.BHC -999.250 RHOZ.PEX 0.053 RXO8.PEX 35.939 RHFT. PEX 23.825 HNPO.PEX 555.200 -999.250 0.055 997.879 23.437 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 6 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NOWiBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0833 FILE SUNk4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10970.0 7020.0 BHC 10926.0 7020.0 PEX 10958.0 7020.0 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE 17 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : ii-JAN-98 8C0-609 1130 Il-JAN-98 2115 Il-JAN-98 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ARRAY INDUCTION PEX PLATFORM EXPRESS $ TOOL NUMBER SDT-C AIT-H HILTB-DTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): FW Dispersed 10.50 66.0 8.6 167.0 O. 213 73.0 O. 162 73.0 O. 149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CNL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW OPENHOLE MAIN LOG DATA SAMPLED AT O. 0833 '. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 18 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP EL~ CODE (HEX) DEPT FT 1092641 O0 000 O0 0 6 1 1 4 68 0000000000 HCAL PEX IN 1092641 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11004.000 HCAL.PEX 4.301 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 19 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~VARY VENDOR TOOL CODE START DEPTH AIT 10970.0 BHC 10928.0 PEX 10957.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 10510.0 10401.0 10420.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ARRAY INDUCTION Il-JAN-98 8C0-609 1130 Il-JAN-98 2115 Il-JAN-98 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL NUMBER SDT-C AIT~H LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 2O PEX PLATFORM EXPRESS HILTB-DTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): FWDispersed 10.50 66.0 8.6 167.0 O. 213 73.0 O. 162 73.0 O. 149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) .. THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CArL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW REPEAT PASS DATA SAMPLED AT O . 5 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 21 TYPE REPR CODE VALUE 4 66 t 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUP~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 GR BHC GAPI 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 TENS BHC LB 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 HTENBHC LB 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 MRES BHC 0PH~41092641 O0 000 O0 0 7 1 1 4 68 0000000000 MTEMBHC DEGF 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 SP AIT MV 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 DT BHC US/F 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PEX CPS 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PEX CPS 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PEX 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PEX 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PEX CPS 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PEX CPS 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 DEVI PEX DEG 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PEX PU 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PEX PU 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PEX PU 1092641 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11004.000 GR.BHC 31.264 TENS.BHC 3618.000 HTEN. BHC ~iRES.BHC 0.074 MTEM. BHC 165.293 SP.AIT -58.813 DT. BHC CNTC.PEX 2333.732 CFTC.PEX 964.147 TNRA.PEX 2.452 RTNR.PEX RCFT. PEX 890.636 RCNT. PEX 2283.812 DEVI.PEX -999.250 NPHI.PEX TNPH. PEX 25.894 NPOR.PEX 25.462 943.482 85.600 2.579 30.013 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 22 DEPT. 10406.000 GR.BHC MRES.BHC 0.085 MTEM. BHC CNTC. PEX 1474.894 CFTC. PEX RCFT. PEX 412.397 RCNT. PEX TNPH. PEX 37.760 NPOR.PEX 121.239 TENS.BHC 155.140 SP.AIT 434.319 TNRA.PEX 1452.754 DEVI.PEX 36.325 7054.000 HTEN. BHC -51.000 DT. BHC 3.323 RTN-R.PEX 9.467 NPHI.PEX 1059.450 105.400 3.768 35.929 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE · FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~94ARY FILE HEADER FILE NUMBER 8 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10970.0 10510.0 BHC 10928.0 10401.0 PEX 10957.0 10420.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: Il-JAN-98 8C0-609 1130 il-JAN-98 2115 il-JAN-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 23 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ~Y INDUCTION PEX PLATFORM EXPRESS $ 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL NUMBER SDT-C AIT-H HILTB-DTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~M) AT TEMPERATURE (DEGF)'. MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TE~fPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FW Dispersed 10.50 66.0 8.6 167.0 O. 213 73.0 O. 162 73.0 O. 149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CArL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW REPEAT PASS DATA SAMPLED AT 0.25'. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.25 FT 36 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUlV~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1092641 O0 000 O0 0 8 1 1 4 68 0000000000 AIBD AIT IN 1092641 O0 000 O0 0 8 1 1 4 68 0000000000 AFiO AIT OP~4M1092641 O0 000 O0 0 8 1 1 4 68 0000000000 AF20 AIT 0H1~41092641 O0 000 O0 0 8 1 1 4 68 0000000000 AF30 AIT 0H~4~I1092641 O0 000 O0 0 8 1 1 4 68 0000000000 AF60 AIT 0H~4~I1092641 O0 000 O0 0 8 1 1 4 68 0000000000 AF90 AIT OPiFIM1092641 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11004. 000 AIBD.AIT 3. 963 AFiO .AIT 1. 028 AF20.AIT AF30 .AIT 1. 828 AF60 .AIT 1. 881 AF90 .AIT 1. 924 DEPT. 10406.250 AIBD.AIT 12.251 AFiO.AIT 1.432 AF20.AIT AF30.AIT 1.853 AF60.AIT 1.959 AF90.AIT 1.706 1. 641 1. 811 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 25 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE · FLIC VERSION : O01CO1 DATE · 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SU~fl~RY VENDOR TOOL CODE START DEPTH AIT 10970.0 BHC 10928.0 PEX 10957.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG IN~fERVAL (FT): LOGGING SPEED (FPHR) : STOP DEPTH 10510.0 10401.0 10420.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ARRAY INDUCTION il-JAN-98 8C0-609 1130 il-JAN-98 2115 il-JAN-98 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL NUMBER SDT-C AIT-H LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 26 PEX PLATFORM EXPRESS HILTB-DTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) .. RESISTIVITY (0t~4~I) AT TE~PERATtrRE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): FW Dispersed 10.50 66.0 8.6 167.0 0.213 73.0 O. 162 73.0 0.149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CNL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW REPEAT PASS DATA SAMPLED AT O. 1667'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 27 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 TT1 BHC US 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 TT2 BHC US 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 TT3 BHC US 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 TT4 BHC US 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 HDRA PEX G/C3 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 PEFZ PEX 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 RHOZ PEX G/C3 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 ~4IN PEX OP~4~ 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 H~NO PEX 0H~41092641 O0 000 O0 0 9 1 1 4 68 0000000000 RXOZ PEX OH~ 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 RX08 PEX 0H~41092641 O0 000 O0 0 9 1 1 4 68 0000000000 HCNT PEX CPS 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 HCFT PEX CPS 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 HGR PEX GAPI 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 RHFT PEX CPS 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 RHNTPEX CPS 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 DPHZ PEX PU 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 HTNP PEX PU 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 HNPO PEX PU 1092641 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11004.000 TT1.BHC 559.600 TT2.BHC 391.600 TT3.BHC TT4.BHC 394.400 ~DRA.PEX -999.250 PEFZ.PEX -999.250 RHOZ.PEX HMIN. PEX 0.102 HFINO.PEX 0.040 RXOZ.PEX 0.030 RXOS.PEX HCNT. PEX 2333.732 HCFT. PEX 964.147 HGR.PEX 31.264 RHFT. PEX RHNT. PEX 2283.812 DPHZ.PEX 60721.211 HTNP. PEX 25.894 HNPO.PEX 568. 800 - 999. 250 O. 030 890. 636 25. 462 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE 28 DEPT. 10406.334 TT1. BHC TT4. BHC 465.600 HDRA. PEX HMIN. PEX O. 051 HFiNO.PEX HCNT. PEX 1480. 816 HCFT. PEX RHNT. PEX 1321.166 DPHZ.PEX 695. 200 TT2. BHC O. 050 PEFZ. PEX 0.053 RXOZ . PEX 426. 055 HGR. PEX 15.152 HTNP . PEX 486. 800 TT3 .BHC 5. 858 RHOZ.PEX O. 057 RX08. PEX 121. 299 RHFT. PEX 39.133 HNPO . PEX 676.800 2.400 0.057 381.932 39.346 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER 10 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10970.0 10510.0 BHC 10928.0 10401.0 PEX 10957.0 10420.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: Il-JAN-98 8C0-609 1130 il-JAN-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 29 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 2115 il-JAN-98 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ARRAY INDUCTION PEX PLATFORM EXPRESS $ TOOL NUMBER SDT-C AIT-H HILTB-DTB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (Otff4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FW Dispersed 10.50 66.0 8.6 167.0 0.213 73.0 O. 162 73.0 0.149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CNL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW REPEAT PASS DATA SAMPLED AT O. 0833 '. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 3O ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HE~) DEPT FT 1092641 O0 000 O0 0 10 1 1 4 68 0000000000 HCAL PEX IN 1092641 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 11004.000 HCAL.PEX 3.963 DEPT. 10406.084 HCAL.PEX 12.251 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 31 **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE · FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION · O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 11 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~D%RY VENDOR TOOL CODE START DEPTH STOP DEPTH BHC 7020.0 6862.0 PEX 7020.0 6862.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC AIT PEX $ BOREHOLE COMP. SONIC ARRAY INDUCTION PLATFORM EXPRESS Il-JAN-98 8C0-609 1130 Il-JAN-98 2115 Il-JAN-98 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL NUMBER ........... SDT-C AIT-H HILTB -DTB LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE 32 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) '. MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FW Dispersed 10.50 66.0 8.6 167.0 0.213 O. 162 0.149 73.0 73.0 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CNL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW MAIN LOG DATA ACQUIRED UP INTO CASING SAMPLED AT 0.5 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 33 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MODNUM~ SAMP ELEM CODE (HEX) DEPT FT 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 GR BHCGAPI 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BHC LB 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 HTENBHC LB 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 CNTC PEX CPS 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 CFTC PEX CPS 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 TNRA PEX 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 RTNR PEX 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 RCFT PEX CPS 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 RCNT PEX CPS 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 NPHI PEX PU 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 TNPH PEX PU 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 NPOR PEX PU 1092641 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 7020.000 GR.BHC 65.663 TENS.BHC 3775.000 HTEN. BHC 900.345 CNTC. PEX 1588.839 CFTC.PEX 511.524 TNRA.PEX 3.035 RTNR.PEX 3.134 RCFT. PEX 476.461 RCNT. PEX 1608.345 NPHI.PEX 32.728 TNPH. PEX 34.818 NPOR.PEX 32.917 DEPT. 6862.000 GR.BHC 42.011 TENS.BHC 3612.000 HTEN. BHC 881.980 CNTC. PEX 1545.054 CFTC.PEX 515.237 TNRA.PEX 3.035 RTNR.PEX 3.652 RCFT. PEX 398.428 RCNT.PEX 1507.314 NPHI.PEX 34.292 TNPH. PEX 32.866 NPOR.PEX 32.263 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 34 **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O. 1667 FILE SO?4~Jh~Y VENDOR TOOL CODE START DEPTH BHC 7020.0 PEX 7020.0 $ LOG HEADER DATA STOP DEPTH 6862.0 6862.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BHC BOREHOLE COMP. SONIC AIT ARRAY INDUCTION PEX PLATFORM EXPRESS Il-JAN-98 8C0-609 1130 Il-JAN-98 2115 il-JAN-98 11094.0 10976.0 6846.0 10960.0 1800.0 TOOL NIJM~ER SD T- C AIT-H HILTB-DTB LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 35 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 6980.0 7020.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) '. MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHF~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FWDispersed 10.50 66.0 8.6 167.0 O. 213 73.0 O. 162 73.0 O. 149 73.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 21-30 Dec 97 Sperry Sun MWD GR Standoffs on AIT and BHC, Bowspring on CArL AIT run Compute Standoff, Eccentered Maximum deviation 48.9 deg There are some intervals with very large washouts. Tools have poor repeatability over these zones. THIS FILE CONTAINS THE RAW MAIN LOG DATA ACQUIRED UP INTO CASING SAMPLED AT 0.1667'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE: 36 TYPE REPR CODE VALUE 7 65 8 68 0.166 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT 1092641 O0 000 O0 0 12 1 1 4 68 0000000000 HCNTRAC CPS 1092641 O0 000 O0 0 12 1 1 4 68 0000000000 HCFTRAC CPS 1092641 O0 000 O0 0 12 1 1 4 68 0000000000 HGR RAC GAPI 1092641 O0 000 O0 0 12 1 1 4 68 0000000000 RHFTRAC CPS 1092641 O0 000 O0 0 12 1 1 4 68 0000000000 RHNTRAC CPS 1092641 O0 000 O0 0 12 1 1 4 68 0000000000 HTNPRAC PU 1092641 O0 000 O0 0 12 1 1 4 68 0000000000 HNPO RAC PU 1092641 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 7020.000 HCNT. RAC 1587.784 HCFT.RAC 508.697 HGR.RAC RHFT. RAC 506.218 RHNT.RAC 1594.139 HTNP.RAC 35.071 HNPO.RAC DEPT. 6862.167 HCNT.RAC 1527.004 HCFT.RAC 485.844 HGR.RAC RHFT.RAC 387.946 R3{NT. RAC 1484.124 HTNP.RAC 33.208 HNPO.RAC 65.871 33.493 40.283 31.705 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAR-1998 12:40 PAGE 37 * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/03/ 6 ORIGIN : FLIC TAPE NAME : 98078 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 13-06A, PRUDHOE BAY, API #50-029-20642-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/03/ 6 ORIGIN : FLIC REEL NAME : 98078 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, 13-06A, PRUDHOE BAY, API #50-029-20642-01
