Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
192-032
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 06/01/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 6/1/2023. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 6/1/2023. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/01/2023Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateL-2072210815002923702003.371.31/23/2023123/1/2023L-2312230105002923746003.003.0-393/27/2023M-111810575002920589002.602.6-105/29/2023M-311920325002922256001.501.5-165/29/2023M-331941165002922504001.301.3-145/29/2023N-171830095002920898001.201.2-115/30/2023N-18A2081755002920906010.500.5-65/30/2023N-21A1961965002921342011.001.0-85/30/2023N-272071045002923365000.500.5-45/30/2023N-292141105002923521002.302.3-245/30/2023N-31215175500292356000-0--205/30/2023V-2342220045002923707006.3210.91/23/2023243/1/2023W-2412221545002923741002.502.5-263/1/2023Z-121891025002921977000.700.7-45/23/2023Z-34212061500292346900-0--155/27/2023Z-402111735002923462000.700.7-65/27/2023Z-46A2052035002923280010.500.5-35/23/2023Z-502120015002923463000.500.5-35/27/2023Z-662121955002923482000.700.7-85/27/2023Z-116211124500292345500-0--175/27/2023Z-210204181500292322600-0--125/27/2023Z-2292221045002923726003.8361.23/5/2023363/27/20231.501.5-5/29/2023M-3119203250029222560016 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, December 19, 2017 2:57 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK,OPS Prod Controllers;AK, OPS Well Pad MN;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Shriver,Tyson; Wellman,Julie; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua;Worthington, Aras J;Wallace, Chris D (DOA); Romo, Louis A;AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer M-31 (PID# 1920320) IAxOA communication mitigated with seal- tite treatment of the wellhead All, Producer M-31 (PTD#1920320)was made under evaluation on 11/21/17 for having sustained outer annulus casing pressure above NOL. Wellhead diagnostics performed on 11/23/17 showed that both the primary and secondary wellhead seals in the inner casing packoff had failed. On 12/9/17 a remedial seal-tite treatment was performed and the well passed a subsequent PPPOT-IC on 12/13/17. The well was brought online 12/12/17 and has shown no signs for OA repressurization or IAxOA communication. The passing pack off test,and stable annuli pressure indicated the seal-tite treatment successfully repaired the IAxOA communication. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED . . WO From: AK, GWO v- • -•rity Engineer Sent: Tuesday, November 2 , ! 1:51 PM To: AK, OPS EOC Specialists; AK, OPS .cility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS ' •- •ntrollers; AK, OPS Well Pad MN; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Eng , • iver,Tyson; Wellman, Julie Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integn GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops ••• Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgom- ravis J; Munk, Corey; 1 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, November 21, 2017 1:58 PM To: Regg,James B (DOA) Cc: AK, GWO Well Integrity Well Information;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer M-31 (PTD# 1920320) Sustained outer annulus casing pressure above NOL Attachments: M-31.pdf All, Producer M-31 (PTD#1920320)was discovered to have sustained inner annulus casing pressure above NOL on 11/21/17. The pressure were confirmed to be T/I/O=480/1430/1270psi. The sustained casing pressure indicates a potential failure of the secondary barrier. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. DHD-OART—Failed on 11/21/17 2. Wellhead—Leak Path Evaluation 3. Production Engineer—Evaluate for seal-tite 4. Well Integrity Engineer—Additional diagnostics as needed Please respond with any questions, Joshua Stephens . Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 NNED W ► SCA STATE OF ALASKA 0 •ALASKA OIL AND GAS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® 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: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 192-032 3. Address: P.O.Box 196612 Anchorage, Development I Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22256-00-00 7. Property Designation(Lease Number): ADL 0028257 8. Well Name and Number: PRUDHOE BAY UNIT M-31 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: rp Total Depth: measured 9945 feet Plugs measured feet RECE'\(ire.6�r/ true vertical 9211 feet Junkmfeet easured J AH N 2 6 2017 Effective Depth: measured 9862 feet Packer measured 8980 feet true vertical 9136 feet Packer true vertical 8344 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 35-115 35-115 Surface 2981 13-3/8"68#L-80 36-3017 36-3017 5020 2260 Intermediate 9236 9-5/8"47#L-80 32-9268 32-8602 6870 4760 Production Liner 940 7"26#13Cr80 8998-9939 8361-9205 7240 5410 Perforation Depth: Measured depth: 9251-9281 feet feet 9386-9396 feet 9396-9411 feet 9411-9416 feet 9416-9420 feet 9420-9436 feet 9436-9504 feet 9514-9536 feet True vertical depth: 8587-8614 feet feet 8709-8718 feet 8718-8731 feet 8731-8736 feet 8736-8739 feet 8739-8754 feet 8754-8815 feet 8824-8844 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 7"Baker Mod DB Perm Packer 8980 8344 true vertical depth) 5-1/2"HRQ SSV 1987 1987 12.Stimulation or cement squeeze summary: Intervals treated(measured): ))E�tt �d, Treatment descriptions including volumes used and final pressure: SCAMS 1 MAR 0 LU 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 166 348 2707 1682 560 Subsequent to operation: 387 1169 5790 1636 437 14.Attachments:(required per 20 AAC 25.070 25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 10 Exploratory 0 Development 11 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignaturePhone +1 907 564 4424 Date 1/26/17 Form 10-404 Revised 5/2015 V Tz- Z` 1 r / /JRBDS Lt/ FEB 3 ���g / Submit Original Only • • m Q, 00 _000 CU N N LS C N in CO I. C) N N- COY) 7 O 00 N r- m Lo CO r 00 1— N CO 0) N O O N- co O CO N N 't co co d) CO 00 O) U) CON0000N- M M M CO N CN CO C '— M Lo N- 0o CA co CO co OE ' MO N O) CA S CA CA OO CA CU gm 111111 U) CD N 0) CO coO Cr) M M 0) N CO C MQ O O co O 0 co \ O c9 O U Ci)Q U J c2 M N co —(Y) 4 • O CO (o M � N O N M- O N LL �)0 co M r- CD C 00 O N Nr CO N N CA CA 00 N w � Q � O 0 ww 7) U U OOu.. ck c ZZ Z �UU) � JF- H . • 10 2 e 0) 2 a II y .---,/ II I q • / ; I & _« o_ 2 21 \ % 7 I a < OR E° 2 w 2 2 % 2 < 2 -® 01 - i- 0 �ƒ � [-•- 20 I � -1 / i O G 0LU / / W ; � � m / % � wo 7 / c / m ¥ 0 � CD II �� 0 �� 2 U) 8w2k � % 0 Oz / * 777 c � 2 0 .- � c � 2 E \ ® 2 mL „wrt E 2 < t \ 0 ƒ X b O D w >- > - cmm / k a � � � > c • I m co c ¥ E F- , M � ! :22 / - < SOF- 0 7k / - O- k g M k ccs w� > oR � L Ieno 3 } o o _ 05 O " - O w z a o g O / z 0 ( c w 0 • b to p � A \ 1102 Lu / 7 �w - tI0 o t W ! ! e w ƒ | 7 _ -� \ a f 5 m L O o O , G w to E L -1 a w 7 0 9 @ G@ _2 112 w 2 < - .- c < o \ E ® Q m@ Q U) � w w w � � � � � / Rrx(NI � � Ko ; We',WZ � � w \ NtIG0 Q 0 � _iCe7b � ® U \ UJ1 . R b > ¥ - « b E 4 « ® / b Q > c wcr e 2 I _ m a Q 2 k $ ƒ / ~ R o k ƒ p ON OEOWXe0o = a222 < kw2WL2 L � 2OE / K ƒ loco- zo - 2w « ? % L = / 2 kwWw5cNu_ \ " � 5 & WpZ \ . RaOS _b = R ƒ i � 03� 03 \ co co -I3 � / ƒ � km _ � R � k _ � ¢ -J0- kz ® w ® 1 \ \ 2 -1000 - ® m \ mmk . E _i Lu = ooL _IL & w < 5 -ILu- o -1 - = / D � QGwu 9 / PE / CC / - IEE -JdaR * 9R * w0 / $ : E : : a a o : : k m a o < 5 e : : : : m 0 . 0 w < o o o I- co 03 / / 2 n 5 / S de (0 ¥ 2 2 » < thILE= • 5 X7 FMC 120 S SA NOTE: WELL REQUIRES A SSSV*** ' D FAC M—31 *�CHROMEE TBGT&LNR** BPV PROFILE IS NOT ACTUATOR= BAKER C INITIAL KB.ELE% 57' BF.ELEV= 26' KOP= 3854' l 1987' 1—j5-1/2"OTRS HXO SSSV LAND NP,D=4.562" Max Angle= 36°@ 5037' Datum M)= 9551' 1987' H5-1/2 HES MO DSSSV,D=3.12"(01/02/17) Datum TVD= 8800'SS GAS UFT MANDRELS 13-3/8'CSG,68#,L-80,D=12.415" H 2977' ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3002 3002 0 OTIS DOME RM 16 03/16/16 6 4712 4642 30 OTIS DOME RM 16 03/16/16 5 6067 5794 29 0115 DOME RM 16 03/16/16 Minimum ID =3.12" @ 1987' 4 7002 6613 28 OTIS SO RM 32 03/16/16 5-1/2" HES HRQ DSSSV 3 7634 7166 30 OTIS DMY RM 0 03/16/16 2 8224 7680 29 OTIS DMY RA 0 05/14/92 1 8847 8226 28 OTIS DMY RM 0 03/16/16 5-1/2"TBG, 17#,13-CR, .0232 bpf,D=4.892" H 8907' • ,— I 8907' --5-1/2"X 4-1/2"XO,ID=3.958" I I 8919' —14-1/2"PARKER SWS NP,D=3.813" Z X 8981' —9-5/8"X 4-1/2"BKR SB-3 (LATCH)FKR,D=3.99" TOP OF 7"LNR — 9013' ' ' 9024' —4-1/2"PARKER SWS NP,D=3.813" 9122' —14-1/2"PARKER SWN NP,D=3.725' 4-1/2"TBG,12.6#,13-CR,.0152 bpf,ID=3.958" — 9134' / \ —` 9134' H4-1/2 VVILEG,D=3-958" 9136' HELM)TT LOGGED 05/22/91 9-5/8"CSG,47#,L-80,D=8.681" —{ 9267' 1 PERFORATION SUMIIAARY REF LOG:SW5 BHCS ON 05/07/92 ANGLE AT TOP PERE:26°@ 9251' Note:Refer to Reduction DB for historical perf data SEE SPF INTERVAL OPN/SQZ SI-OT SQZ 3-318" 4 9251-9281 0 12/28/16 3-3/8" 4 9386-9504 0 05/23/92 3-3/8" 4 9514-9536 0 05/23/92 PBTD H 9862' .1.**... •.,..s...,.,.,. 7"LNR,26#,13-CR,.0383 bpf,D=6.276" H 9940' WAWA.* DATE REV BY CONVENTS DATE REV BY COMIVB'TTS PRUDHOE BAY UNIT 05/14/92 ORIGINAL COMPLETION 01/20/15 BSE/JMD SET RQ DSSSV(01/12/15) WELL: M-31 12/20/10 NAB/JMD ADDED SSSV SAFETY NOTE 03/18/16 RCT/JI D RESET DSSSV/GLV C!O(03/16/16) PERMIT No: 1920320 05/13/13 TJWJMD ADDED 4-1/2"XX PLUG(05/03/13) 12/28/16 ZV/JMD PULLED DMY SSSV(12/27/16) API No: 50-029-22256-00 05/22/13 DU/JMD TREE Q0(05/19/13) 12/29/16 JUJMD ADFERFS(12/28/16) SEC 1,T11N,R12E 2082'FM_&606'R9_ 05/25/13 SWC/PJC PULL XX RUG 01/10/17 DG/JMD SET DSSSV(01/02/17) 11/21/14 TJWPJC'SSSV NP UPDATE BP Exploration(Alaska) • VOF Th. • y9 ////, '� � ��e THE STATE Alaska Oil and Gas o f® T c Conservation Commission 1,4 333 West Seventh Avenue z'— Anchorage,e, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov January 17, 2017 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: No-Flow Verification .r kI&MED JAN 2. 6 2117, PBU M-31 PTD 1920320 Dear Ms. Cocklan-Vendl: On January 14,2017 an Alaska Oil and Gas Conservation Commission(AOGCC)Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit M-31. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit M-31. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(Z)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank,the tubing pressure monitored at the production tree bled to zero within 3.5 minutes. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit M-31 demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, Jam , .3. James B. Regg l Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDC WellIntegrityCoordinatorabp.com Ryan Daniel, BPXA • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 1/14/2017 P. I. Supervisor FROM: Bob Noble SUBJECT: No Flow Test Petroleum Inspector PBU M-31 BPXA PTD 1920320 1/14117: I traveled to BPXA's PBU M-31 at 8:30 am to witness a no flow test. I met with BPXA representative Josh Murphy and we went over the rig up and details of the no flow test procedure. Everything looked good. Josh departed location and left DHD representative Scott Byars in charge of the test. The well was open to atmosphere and tubing pressure was 0 psi prior to the start of the test. The following table shows test details: Pressures' Flow Rate Time Remarks (psi) Gas - scf/hr Liquid - gal/hr 9:10 AM 0/76/180 Shut well in for 3 hour test ' 10:10 AM 4/73/180 Well shut in 11:10 AM 6/73/170 - Well shut in 12:10 PM 8/73/170 • Open tubing up to bleed off - 1 Pressures are T/IA/OA Summary: At 12:15 PM after a 3-hour built up time the tubing had 8 psi. The tubing ,7 was opened and it took 3.5 minutes to bleed to 0 psi with flow going to the tank. All flow was gas with no sign of fluid. ' � ti�Se� Attachments: none SCANNED MAY _ 120!1 2017-0114_N o-FlowPBU_M-31_bn.docx Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, February 08, 2015 6:44 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA) Subject: OPERABLE: Producer M-31 (PTD#1920320) Passing NFT, Permission to Flow Well Without Sub Surface Safety Valve Attachments: image001 jpg; image002.png; BPXA No-Flow Verification, PBU M-31.pdf All, Producer M-31 (PTD#1920320) passed an AOGCC witnessed no flow test(NFT)on January 21, 2015. The no flow test confirms that the well is not capable of unassisted flow of hydrocarbons to surface. The AOGCC has approved BP to produce the well without a sub-surface safety valve (SSSV). The well has been reclassified as Operable and may be placed on production without a SSSV. A NFT must be performed again if the well is perforated, cleaned out, stimulated in any way, or shows any sign of being capable of flowing hydrocarbons to surface unassisted. BP Base Management shall monitor for changes in flow characteristics to ensure the well remains incapable of flowing hydrocarbons to surface. The approval letter from the AOGCC is attached. Please call with any questions. Thank you, SCANNED W,i, (2 Kevin Parks Alternate Laurie Clime?) BP Alaska-Well Integrity Coordinator GINGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Se . da , January 24, 2015 10:12 PM To: AK, OPS GC • • I. OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D& ' - •I- Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB Eas - •st Engr; Peru, Cale; AK, OPS Well Pad MN Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD - • -•rity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: NOT OPERABLE: Producer M-31 (PTD #1920320) Passing NFT, waiting OGCC approval 1 iL OF T�� I�y, sTHE STATE � Alaska Oil and Gas 'a ofALASIc:A Conservation Commission 'l •t= 333 West Seventh Avenue =vim GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rh Main: 907.279.1433 OFALAS Fax. 907.276 7542 www.aogcc.alaska.gov February 6, 2015 Mr. Randy Redmond Onshore Site Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 SCANNED FEB p 6 ii I , RE: No-Flow Verification PBU M-31 PTD 1920320 Dear Mr. Redmond: On January 21, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit M-31. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit M-31. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank, Prudhoe Bay Unit M-31 demonstrated the discharge of well pressure within two minutes. Liquid and gas flow rates during a fifteen-minute flow monitoring period were not measurable. The subsurface safety valve must be returned to service if Prudhoe Bay Unit M-31 demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, James B. Regg Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg keel DATE: January 21, 2015 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector PBU M-31 BP Exploration PTD #1920320 Wednesday, January 21, 2015: I witnessed the No Flow test for the above mentioned well. I met Leighton (Lee) Grey and Brian Womac at the appointed time on location. The well was open to a horizontal tank with no discernable flow. The well was shut-in at the wellhead and tubing pressure was recorded on a digital recording gage. After three hours shut-in time the tubing was opened to tankage. Tubing pressure was discharged within two minutes and the well was observed in this condition for an additional thirteen minutes. The data is attached to this report in the form of an excel file. The following table shows test details: Time Pressures1 Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 0:00:00 1/263/520 - None None Open to Tankage/SI tubing 1:00:00 6/262/515 - Shut-in Shut-in Monitor well 2:00:00 10/262/510• Shut-in Shut-in Monitor well 3:00:00 14/262/510 ' Shut-in Shut-in Open to Tankage 3:00:30 - 10/262/510 • Unknown Unknown Open to Tankage 3:01:00 - 5/262/510 Unknown Unknown Open to Tankage 3:01:30 - 2/262/510' Unknown Unknown Open to Tankage 3:02:00 • 0/262/510 - Unknown Unknown Open to Tankage 3:03:00 • 1/262/510 - None Discernable None Discernable Open to Tankage 3:04:00 . 0/262/510 - None Discernable None Discernable Open to Tankage 3:05:00 • 0/262/510 - None Discernable None Discernable Open to Tankage 3:10:00 - 0/262/511 - None Discernable None Discernable Open to Tankage 3:15:00 - 0/262/512 - None Discernable None Discernable Open to Tankage 1 Pressures are T/IA/OA Summary: This well appears to meet the criteria for consideration of no-flow status by the Commission. Attachments: M-31 TBG AOGCC NFT 1-21-15.xls SCANNED 1, y ; „LJ; 2015-0121_No-Flow_PBU_M-31_1g.docx Page 1 of 1 )-- pr--k 1,,( ---?, 1 (pr6 Ftw32z) ik4 (i6 Data Collection Report -- `+ J Prnss;,v•t.__ Chassis Left Scale Right Scale Serial Number 072845 073257 073251 Datatype Lower Upper Units PSI G PSI G Lower Upper PSI G Tag 1Qw- 21-Jan-15, 08:37:41, 2347 PSI G 16 - — 0 14 — 0 12 ri — 0 10 8 -1 6 — -1 4 - - -1 2 0 , 11 -1 z, D0 06 (1.b '�� 00 tk0 ^�6 L t. 00* 00* 00* 0j 0� Oct'. Orl' 00. 00. Elapsed Time hh:mm:ss PSI G PSI G XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ,~-~ of Well History File File Number PAGES TO DELETE Complete RESCAN r'l Color items- Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Odginal-- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSlZE/D/ Logs'of vadous kinds . COMMENTS: Scanned by: Beverly Dian(~~athan Lowell Date: ¢/~'~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: lsl • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg � AUG 01 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 0 Anchorage, Alaska 99501 lq� Subject: Corrosion Inhibitor Treatments of GPB M -Pad 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • I I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) M-pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.65 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA _ NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029 222550000 0.5 NA 0.5 NA 3.4 6/3/2009 •4 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 Y ~ ~ ~ STATE OF ALASKA ~~0~ ~n , ' ALA A OIL AND GAS CONSERVATION COM SIGN ~~r ~ ~ , ,,,~7 REPORT OF SUNDRY WELL OPERATI4~~ - ~' ,.,,,,My~-1 1. Operations Abandon ~ Repair Well 0 ~ Plug Perforations ~ Stimulate _ FALTITE Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ' 192-0320 J 3. Address: P.O. Box 196612 Stratigraphic Service ~~ 6. API Number: , Anchorage, AK 99519-6612 50-029-22256-00-00 7. KB Elevation (ft): 9. Well Name and Number: 57 KB PBU M-31 ' 8. Property Designation: 10. Field/Pool(s): ADLO-028257 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9945 - feet Plugs {measured) None true vertical 9210.52 , feet Junk (m a sured) None e y y~~~y~g~, y~ y 't9 ~~v .~ `~ ~UUI Effective Depth measured 9862 feet true vertical 9136.21 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 33 - 113 33 - 113 1490 470 Production 9236 9-5/8" 47# L-80 31 - 9267 31 - 8601.53 6870 4760 Liner 927 7" 26# 13CR80 9013 - 9940 8373.74 - 9206.04 7240 5410 Surface 2983 13-3/8" 68# L-80 35 - 3017 35 - 3017 4930 2270 Perforation depth: Measured depth: 9386 - 9396 9386 - 9411 9386 - 9436 9420 - 9504 9436 - 9504 9514 - 9536 True Vertical depth: 8709 - 8718 8709 - 8731 9709 - 8754 8739 - 8815 8754 -.8815 8824 - 8844 Tubing: (size, grade, and measured depth) 5-1/2" 17# 13Cr80 29 - 8908 4-1/2" 12.6# 13Cr80 8908 - 9135 Packers and SSSV (type and measured depth) 4-1/2" Baker Mod DB Perm Packer 8981 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 540 3054 3384 335 Subsequent to operation: 639 2795 5173 438 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~ WAG GINJ ~" WIND WDSPL ~~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-337 Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 12/5/2007 Form 10-404 Reed 04/2006 + ~ Submit Original Only .. ~ ~~, )t'i, ~ ,~ 7UQ7 C M-31 • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY acrivmraaTE suM~aRY 11/13/2007 T/I/O = 1410/1280/540. Temp = SL Bleed IAP to 0 psi (Assist Seal Tite). AL SI casing & Lateral valves. ALP = 600 psi. IA FL @ 8981' (Below sta. #1). Bled IAP from 1280 psi to 940 psi in 1 hr down M-12 fiowline to CLP. Resumed bleeding IAP from 940 psi to 120 psi in 4 hrs to DHD U/T. Monitor for 30 min. Pressures unchanged. ""` Note"' Heater is on well head left doors open. 11!13/2007 T/I/O = SSV/1280/260. Temp = SI. WHP (Pre Sealtite). IA FL @ 8981' (below sta#1)(481 bbls). Check far heater. Currently no heaters available. 11/14/2007 T/I/O = 1410!120/540. Temp = St. Bleed IAP 8~ OAP to 0 psi (Assist Seal Tite). AL St @ casing & lateral valves. ALP = 600 psi. IA FL @ 8991' (Below sta. #1). Bled IAP from 120 psi to 0 psi in 2 hr to DHD U/T. OA FL. @ 270'. Bled OAP from 540 psi to 0 psi in 1 hr 20 min to slop trailer. Monitor for 30 min. Pressures are unchanged. FWHP's = 1410/0/0 **Note grease zerk on SSV leaking small amount of gas, Notified pad operator & grease crew to service. Heater is on well & man doors were left open. 11/16/2007 T/IA/OA= 1300/0/0 Temp=Sf Assist Seal-Trte Intemationat (G{y-Flo packed 1C void ) RU HP bleed tool onto IC test void, 200 psi to 0 psi. Remove 2 Alemite fittings, install 2 HOKE valves. RU seal-tile test pump to fC void and flush with Gly-Flo until clean returns achieved. PT to 3500 psi for 15 minutes, 3250/ 15 minutes, (2nd test) PT to 3500 psi for 30 minutes, 3300/ 15 minutes, 3250/ 30 minutes. (3rd test) PT to 3500 psi for 1 hour, 3300/ 30 minutes, 3200/ 60 minutes. Allowed pressure to remain in void for additional hour before last test. (4th test) PT to 3500 si for 30 minutes 3500/ 15 minutes .Bled void to 500 psi, RD test equipment. 11/16/2007 T/I/0=1410/8/13. Temp=St. Bleed lAP lii OAP to 0 psi {assist Seat Tite). to FL 8991' (below sta #1 }. OA FL @ 270'. Bled IAP to bleed trailer from $ psi to 0 psi in 20 min (alt gas}. Bled OAP from 13 psi to 0 psi in 5 min (all gas). Post 30 monitor. Final WHPs=1410/0/0. 11!19!2007 T/{/0= 1420!16/26. Temp=Sl. ALP= SI. OART {evaf IA~cOA comet post Sealtite). IA FL @ 3002' (sta 7). OA FL @ 288' {16.7 bbls). Increased IAP from 16 psi to 700 psi in 4 hours via iumper from M-12 AL tine. IA FL depressed to 8729' (382.3 bbts) while staGcing out the IA. No change in TP or OAP. Final WHP's= 1420/700/26. 11/20/2007 T/t/O =1420/770/26. Temp = SI. OAR7 (eval IAxOA Comm Est Seal-Tite). ALP = SL IA FL @ 8729` (near SOGLV). OA FL ~ 294'. Increased IAP from 770 psi to 1100 psi in 2-1/2 hours lumped from M-12 AL line. lA L unchanged. orntor ror su mm. n-o mange in pressures or riL. i aggea wen vAK r m progress. Notified pad operator. FWHP's = 1420/1100/26 • • 11/21/2007 T!I/O = 1420/1120/30. Temp = St. Monitor, OART (eval IAxOA comm post Sealtite) Day 1. AL SI @ casing valve, ALP = 620 psi. TBGP unchanged. IAP increased 20 psi. OAP increased 4 psi overnight. 11/22/2007 T/1/0=1420/1120/40. SI. Monitor, OART (eval IA x OA comm post Sealtite) day 2. IAP unchanged. OAP increased 10 psi. 11/24/2007 T/1/O = 1420/1120/30. Temp = SI. Monitor, DART (evat IAxOA Comm post Sealtite) Day 4. TBGP unchanged. IAP unchanged. OAP decreased 10 psi. 11/25/2007 T/1/O = 1420/1120/40. Temp = SI. Monitor, DART (eval IAxOA Comm post Sealtite) Day 5. AL SI ~ casing valve, ALP = 620 psi. TBGP unchanged. IAP unchanged. OAP increased 10 psi overnight. 11/2812007 TI11O = 430/1710!80. Temp =Hot. OART (Eva! lAxE3A comm. A/L connected and open @ gate valve. OA FL @ 190'. Bled OAP to 30 psi in 25 min. Monitored for 1 hr. OAP increased to 40 psi. No change in OA FL. Final WHPs = 430/1710/40. 11/29/2007 T/I/O = 400/1600/40. Temp = 124 deg. Monitor, DART (eval IAxOA Comm) day 1. AL line open @ casing valve. TBGP decreased 30 psi. IAP decreased 110 psi. OAP unchanged overnight. 11/30/2007 T/f!O = 350/1550/60. Temp = 116". DART (eval IAxOA Comm) day 2 H2S. TBGP decreased 50 psi, IAP decreased 50 psi, & OAP increased 20 psi overnight. 12/1/2007 T/t/0= 260/1580/60. Temp= Hot. DART (eval IAxOA Comm) day 3. AL online, ALP= 1600 psi. TP decreased 90 psi, IAP increased 30 psi, OAP unchanged overnight. 12/2/2007 T/1/O = 330/161080. Temp = 114 deg. DART (eval TxIA comm) day 4. AL line open @ casing valve. TBGP increased 70 psi. IAP increased 30 ps'r. OAP increased 10 psi overnight. 12/3/2007 T/U0=340/1570!90. Temp=Hot. DART (evat IAxOA Comm) day 5. A/L online. TP increased 10 psi, IAP decreased 40 psi & OAP increased 20 psi overnight. 12/5/2007 Seal tite to wellhead on 11-20-07, Cold OART from 11-21-07 to 11-25-07, Hot OART from 11-27-07 to 12-3-07,10 psi/day BUR, now operable • • ~ ~ ~~ ~ ~ ~ ~ SARAH PAULA, GOVERNOR ~ ~r ~ L+B~ O~ ~D ~~ 333 W. 7th AVENUE, SUITE 100 CO1~T5~`RQA'1'IO1~T COMI-IIS51ON ANCHORAGE, ALASKA 99501-3539 PFIONE (907) 279-1433 FAX (907) 276-7542 Don Brown Pad Engineer BP Exploration Alaska Inc. ~E~'~~~~'~ ~~~~ 1 ~ ~~~~ PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU_,1V1-31 ~~, Sundry Number: 307-337 1(~ 1- Dear Mr. Brown: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this day of November, 2007 Encl. ~ ~1~~~ ~ RECEi~/E l ~ STATE OF ALASKA 1~~ l ALASKA OIL AND GAS CONSERVATION COMMISSION ~~1 ~~V ~ ~ 207 APPLICATION FOR SUNDRY APPROVska Oil & Gas Cons. Commission ~n AAC ~s ~Rn ~__~_.___ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ^ Repair well Q Plug Perforations^ Stimulate ^ Time Extension ^ SealTite Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory ^ 192-0320 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: _ Anchorage, AK 99519-6612 50-029-22256-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU M-31 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028257 - 57 KB - PRUDHOE BAY Field ! PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD {ft): Total Depth TVD {ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9945 ~ 9210.52 - 9862 9136.21 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 33 113 33 113 1490 470 Production 9236 9-5/8" 47# L-80 31 9267 31 8602 6870 4760 Liner 927 7" 26# 13CR80 9013 9940 8373 9206 7240 5410 Surface 2983 13-3/8"68# L-80 35 3017 35 3017 4930 2270 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9386 - 9396 8709 - 8718 5-1/2" 17# 13Cr80 29 - 8907 9386 - 9411 8709 - 8731 4-1/2" 12.6# 13Cr80 8907 - 9134 9386 - 9436 9709 - 8754 - 9420 - 9504 8739 - 8815 - 9436 - 9504 8754 - 8815 - 9514 - 9536 8824 - 8844 - Packers and SSSV Type: 9-5/8"x4-1/2" BAKER SB-3 Packers and SSSV MD (ft): 8981 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1 1 11 9/2007 OIL ~ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Don Brown Printed Name Don Brown Title Pad Engineer Signature Phone 564-4323 Date 11/5(2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: JI.J~ ' 3,~j ~" Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. . P ~~.:: NC~V si ~ 20D7 Subsequent Form Required: "'~~ APPROVED BY /j Approved by: I THE COMMISSION Date: '~ ~j ~ Form 10-403 Revised 06!2006 `-~ l.! (~ ~ U ~ ~ ~ h I... Submit in Duplicate ~ • • by Don Brown M, P, R & T Pad Enginerr BP Exploration (Alaska) Inc. GPB Water Flood Team 900 East Benson Boulevard Direct: (907) 564-4323 Browd2~bp.com P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date November 05, 2007 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-22256-00-00 Permit # 192-032, PBU M-31 Dear Thomas E. Maunder BP Exploration (Alaska) Inc is requesting approval to use Seal-Tite to achieve and prevent IA to OA communication. The objective is to correct communication from inner to outer casing via inner casing hanger using Seal-Tite procedures and sealants. This is an operable well currently shut in due to communication between the inner annulus and outer annulus when the well is on-line. The lower primary casing hanger seals are confirmed to be leaking as applied outer annulus pressure is observed in the casing hanger void area. It is unclear if the upper secondary casing hanger seals are leaking or if this well has a casing leak. Included are the steps for proposed procedure that Seal-Tite will use. Sincerely ~~ ~ Don Brown • Seal-rite International Advanced Sealant Technology Field: Prudhoe Bay Well: M-31 Objective Date: 02 November 2007 Correct communication from inner annulus to outer annulus via the casing hanger using Seal-rite procedures and sealants. Mechanical Considerations This is an operable well currently shut in due to communication between the inner annulus and outer annulus when the well is on-line. The lower primary casing hanger seals are confirmed to be leaking as applied outer annulus pressure is observed in the casing hanger void area. It is unclear if the upper secondary casing hanger seals are leaking or if this well has a casing leak. The purpose of this procedure is to inject Seal-Tite sealant into the casing hanger void area to achieve a seal and prevent IA to OA communication. Intended Diagnostic Procedure 1. Meet with field personnel. Review well history. Verify condition of well as matching information provided. Confirm diagnostic and repair objectives. 2. Perform Job Safety Analysis with all concerned personnel. 3. Record all tubing and casing pressures. 4. Locate the test ports for the inner casing hanger. Confirm the routing and purpose for each port. Note: This well is presumed to have a one plastic injection port and one bleed port for the upper secondary seals. There should be two test ports for the void area between the secondary seal and the primary pack-off seal. 5. Install pressure relief tool with gauge on each void area test port. 6. Sting in and record the pressure in each test port. Compare with adjacent casing pressures. Attempt to bleed test port pressure to zero and note type fluid recovered. • Seal-Tite International Seal-rite International Proposed Procedure 50o Deer cross Driae BP Alaska Well M-31 Madisonville, I,A 70447 Correction of Casing Hanger Leak November 02, 2007 Telephone: 985-875-1292 Facsimile: 985-875-0687 http://www.seal-tite.net 7. Monitor pressure build up rate in each test port. 8..While moni ng void pressure, altering inner a~lus pressure, then outer annulus pressure to confirm which seals (primary and/or secondary) are leaking. 9. Bleed the void and both annuli to zero and remove any check valves and install ball valves on the void area test ports. Rig up Seal-Tite pump to void test port and perform 200 psi low pressure test for 5 minutes and high pressure test (500 psi above required test pressure) for 10 minutes. 10. Pump hydraulic fluid to confirm communication between test ports if possible. Then close opposing test port. 11. Pressure test with hydraulic fluid into test port and measure leak rates at 1000 psi and 2000 psi above opposing casing pressure and at required test pressure for the hanger. Note: Check for records of any plastic packing grease having recently been injected into the test ports. If so, inject Valve-Flush and/or diesel to dissolve/remove potential plastic packing from the seal areas prior to pumping pressure activated sealant. 12. Report diagnostic results to the office. Note: The leak rate @ 2000 psi differential pressure or required test pressure, whichever is higher, should determine which sealant to use. Rule of thumb: 0.00 - 0.75 lit/min @ 2000 psi 0.75 - 1.50 lit/min @ 2000 psi 1.50 - 2.25 lit/min @ 2000 psi 2.25 - 3.00 lit/min @ 2000 psi > 3.00 lit min @ 2000 psi - Gly-Flo Sealant - Tur-Flo Sealant - Pac-Seal Sealant - Pac-Seal Sealant with Angel Hair - Flex-Plug Sealant Intended Repair Procedure for Pressure Activated Sealants 13. Fill the void area with sealant. If possible, inject sealant into one test port until returns observed from a second test port to confirm when the area is full of sealant. Otherwise, pump/inject sealant into the seal area until a pressure increase is seen to indicate that the seal area is full. 14. Inject sealant until a seal is obtained at 500 to 1000 psi differential pressure. Hold for 15 minutes. 15. Increase pressure in 500 to 1000 psi steps every 15 minutes until a seal is obtained at required test pressure for the hanger (or minimum 1000 psi differential pressure). Note: It may be necessary to pump sealant into the secondary seal plastic packing port to seal the secondary seal before pumping sealant into the void to seal the primary seal and achieve a void test. 16. Cycle the injection pressure from zero (or leak source pressure) to test pressure several times to force additional sealant into the leak site. .~ ~ • 17. Lock in test pressure and allow the seal to cure for 6 hours. 18. Pressure test for 15 minutes and record results. 19. Bleed seal area to zero and monitor for pressure build-up. Note that positive pressure may be required to maintain the seal against opposing well pressure. 20. Put the well on stream and monitor for leakage or pressure build up due to thermal effects until reaching normal operating pressure and temperature. 21. Hand well over to Operator. Intended Repair Procedure for Flex-Plug Sealant 22. Mix and blend a 1.liter batch of Flex-Plug. Pour a small sample into a cup and pour the rest into the injection cylinder. Wait 10 to 15 minutes to allow the Flex-P{ug to begin solidifying. 23. Inject 300 ml of Flex-Plug into the seal area. Note injection pressure. 24. Wait 10 to 15 more minutes and inject another 300 ml of Flex-Plug into the seal area. Note injection pressure. 25. Wait 10 to 15 more minutes and inject the remainder of the Flex-Plug into the seal area. The objective is to form a support base in the seal area around and above the leaking seal to allow for the accumulation of additional Flex-Plug injections above it. 26. Flush the test port with 50 ml of hydraulic oil. 27. Flush and clean the injection cylinder and hose with hydraulic oil and prepare for the next Flex-Plug injection. Note that it may be possible to mix the next batch of Flex-Plug while the previous batch is being injected to avoid having to flush the injection cylinder, hose and wellhead outlet with hydraulic oil after each injection. 28. Inject additional Flex-Plug (one liter at a time) to fill the seal area and support test pressure (or minimum 1000 psi differential pressure). The intent is to inject the last of the Flex-Plug at or near required test pressure for the hanger (or minimum 1000 psi differential pressure). 29. Flush the test port with 50 ml hydraulic fluid. 30. Flush and clean the injection cylinder and hose with hydraulic oil. 31. Shut in applied pressure and allow the Flex-Plug to cure for minimum 6 hours. 32. Test via test port with hydraulic oil to test pressure for 15 minutes and record results. 33. If a slight leak is observed, inject pressure activated sealant into the test port to complete the sealing process. 34. Bleed test port to zero and monitor for pressure build-up. Note that positive pressure may be required to maintain the seal against opposing well pressure. 35. Put the well on stream and monitor for leakage or pressure build up due to thermal effects until reaching normal operating pressure and temperature. 36. Hand well over to Operator. Intended Repair Procedure to Seal from Above 37. Confirm the inner casing and outer casings are full of fluid (no gas in the annuli). Capture a sample of the inner casing fluid. 38. Rig up Seal-Tite injection system to the inner casing annulus valve and pressure test. 39. Prepare sealant pill. Take a sample of the sealant and confirm that it floats on the sample of the casing fluid. 40. With required test pressure (minimum 500 psi above normal casing pressure) in the casing, commence injecting Seal-Tite sealant pill into the inner casing valve. Inject enough sealant to fill the upper 5 feet of the inner casing (production annulus) with sealant. 41. Open the inner casing hanger void area test port and take returns through the test port until sealant observed flowing from the test port. 42. Shut in void area test port and open outer casing valve. 43. Monitor flow until the hanger leak is sealed and flow from the outer casing valve stops. 44. Let the seal cure for 3 hours. 45. Bleed inner annulus pressure off to whatever pressure desired by customer. 46. Put the well on production and monitor for leakage or pressure build up due to thermal effects until reaching normal flowing temperature. 47. Hand well over to Operator. END xc: . STATE OF ALASKA RECIED ALAS Oil AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OÆf:tA ÔNS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforation ~ka On>~B'ä~~ rnm . Ç>ther 0 Secure well Perforate New Pool D v1tW~.1!" S. ""N/fl~m1Jion D Perforate D 1!t - Dr Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: Development P Exploratory 192-0320 Stratigraphic Service 6. API Number: 50-029-22256-00-00 57 KB 8. Property Designation: ADLO-028257 11. Present Well Condition Summary: Total Depth measured 9945 feet true vertical 9210.52 feet Effective Depth measured 9862 feet true vertical 9136.21 feet Casing Length Size MD Conductor 80' 20" 91.5# H-40 33' - 113' Liner 927' 7" 26# 13CR80 9013' - 9940' Production 9231' 9-5/8" 47# L-80 34' 9267' Surface 2983' 13-3/8" 68# L-80 35' - 3017' Perforation depth: Measured depth: 9836' - 9411' True Vertical depth: 8708.8' - 8731.34' 9420' - 9504' 8739.45' - 8815.02' Tubing: (size, grade, and measured depth) 5-1/2" 17# Packers and SSSV (type and measured depth) 9. Well Name and Number: PBU M-31 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) None Junk (measured) None TVD Burst Collapse 33' - 113' 1490 470 8374' - 9206' 7240 5410 34' -8601' 6870 4760 35' - 3017' 4930 2270 9436' - 9504' 8753.86' - 8815.02' 9514' - 9536' 8824.01' - 8843.77' 13Cr80 29' - 8908' 4-1/2" Baker Mod DB Perm Packer 8981 12. Stimulation or cement squeeze summary: Intervals treated (measured): Repres'entåtive Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 4155 3066 0 9578 5447 0 15. Well Class after Droposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 582 1001 x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble , RBDMS 8Ft 0 CT 0.3 2D06 Tubing pressure 405 420 Service WINJ WDSPl Title Data Engineer Signature Phone 564-4944 Date 9/27/2006 sedeR I GI NAL Submit Original Only ~ .~ . . M-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/11/2006 ***WELL SHUT IN ON ARRIVAL*** PULL PX PRONG @ 9001' SLM SET STA# 1 SIO GLV 22/64" WI RA LATCH @ 8846' MD (8831' SLM) PULL PX PLUG BODY @ 9000' SLM. ***GIVE WELL BACK TO DSO, LEFT SI*** FLUIDS PUMPED BBLS I 1 DI ESEL 1 TOTAL . 1J/%tt' hJ¿ STATE OF ALASKA A ALASKA Oil AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well [2] Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 57 KB 8. Property Designation: ADlO-028257 11. Present Well Condition Summary: Total Depth measured 9945 feet true vertical 9210.52 feet Effective Depth measured 9862 feet true vertical 9136.21 feet Casing length Size Conductor 80' 20" 91.5# H-40 Liner 927' 7" 26# 13CR80 Production 9231' 9-5/8" 47# l-80 Surface 2983' 13-3/8" 68# l-80 Perforation depth: Measured depth: 9836' - 9411' True Vertical depth: 8708.8' - 8731.34' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl 582 1001 RECEIVED SEP 1 3 2006 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic StimulateD Gas Con~ Cøm . WaiverD Time ExtensionD Anchora e FAISS' n Re-enter Suspended Well D g 5. Permit to Drill Number: Exploratory Service 192-0320 6. API Number: 50-029-22256-00-00 9. Well Name and Number: PBU M-31 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Plugs (measured) None Junk (measured) None 20r)f' ~CÁNNED SEP 1 ~j ... Uu MD TVD Burst 33' - 113' 33' - 113' 1490 9013' - 9940' 8374' - 9206' 7240 34' - 9267' 34' -8601' 6870 35' - 3017' 35' - 3017' 4930 Collapse 470 5410 4760 2270 9420' - 9504' 9436' - 9504' 8753.86' - 8815.02' 9514' - 9536' 8739.45' - 8815.02' 8824.01' - 8843.77' 5-1/2" 17# 13Cr80 29' - 8908' 4-1/2" Baker Mod DB Perm Packer 8981 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 4155 3066 0 9578 5447 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 405 420 Service WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowtedge. WINJ Contact Gary Preble Signature Title Data Engineer Phone 564-4 Date 9/8/2006 SEP 1 4 2006 Submit Original Only . . M-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY T/I/O=90/62/0+, Temp=SI. Braidenhead weld (COMPLETE). Assist welders with braiden head weld. Monitor N2 purge. FWHP=90/6010+. 6/1 T/I/O 1001010 Freeze Protect TxlA (Shut In)(Post Braiden Head Weld.) Hardline between IA & Flowline had been removed. Spear in to IA w/2 bbls meth by 147 bbls 50* Diesel into IA wi returns from TBG to Flowline. Shut In Flowline. U-Tube TxlA. Final WHP's=110/11010 FLUIDS PUMPED I BBLS I 2 METH 147 DIESEL 149 TOTAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ UA GEL. SQUEEZE PuU tubing _ Alter casing _ Repair well _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 57 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2082' FNL, 606' FEL, Sec. 01 T11 N, R12E, UM (asp's 628213, 5974274) M-31 At top of productive interval '~ 9. Permit number / approval number 5097' FNL, 2016' FEL, Sec. 36, T12N, R12E, UM (asp's626764, 5976514) ~ 192-032 At effective depth 10. APl number 4915' FNL, 2117' FEL, Sec. 36, T12N, R12E, UM (asp's 626660, 5976695) 50-029-22256-00 At total depth 11. Field / Pool 4882' FNL, 2135' FEL, Sec. 36, T12N, R12E, UM (asp's 626641, 5976727) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9945 feet Plugs (measured) true vertical 9211 feet Effective depth: measured 9862 feet Junk (measured) true vertical 9136 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 141' 141' 2085 cf Class 'G', 425 cf Surface 2946' 13-3/8" 2977' 2977' Class 'G' 2022 cf Class 'G', 150 cf Intermediate 9236' 9-5/8" 9267' 8602' Class 'G' Liner 927' 7" 290 cf Class 'G' 9013' - 9940' 8374' - 9206' RECEIVED Perforation depth: measured Open Peris 9386'-9504', 9514'-9536' APR 1 $ 2003 true vertical Open Peris 8709'-8815', 8824'-8844' Alaska 0il & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2" 17# 13CR TBG to 8907'. 5-1/2" X 4-1/2" XO @ 8907'. 4-1/2" 12.6# 13CR TBG @ 9134' Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" Baker SB-3 (LATCH) PKR @ 8981' MD. 5-1/2" Otis SSSV Landing Nipple @ 1987'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SHUT-IN Subsequent to operation SHUT-IN 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ ~ ......... ... Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~e~.~,,~~..~.~.~.~ Title: Technical Assistant Date April 17, 2003 DeWayne R. Sc norr .~. , .... Prepared by DeWar/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88' N R I GIN A L 'x" M-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03~03~2003 ANN-COMM (WAIVER COMPLIANCE): AC-FLUID LEVEL 0312012003 ANN-COMM (WAIVER COMPLIANCE): AC-BLEED; AC-FLUID LEVEL 04/0312003 ANN-COMM (WAIVER COMPLIANCE): GEL TREATMENT 04~04~2003 ANN-COMM (WAIVER COMPLIANCE): AC-BLEED 0410512003 ANN-COMM (WAIVER COMPLIANCE): AC-MONITOR EVENT SUMMARY 03~03/03 TIO: 1760/1800/800. OA FL @ 1686' (PREP FOR OA GEL SQUEEZE). 03/20/03 T/110=170011740/900 BLEED OA (FOR F.B.). OA FL @ 1800' (104 BBLS). BLED OA FROM 900 PSI TO 580 PSI IN 1.5 HOURS. OA FL REMAINED @ 1800'. MONITORED OAP FOR 30 MINUTES, OAP INCREASED 10 PSI. FINAL WHP's 1700/1740/590. 04/03/03 PUMPED OA JUNK GEL SQUEEZE PER PROCEDURE USING 2500# OF 100 MEASH, 900# BENTONITE AND CELOFLAKE. OA LOCKED UP TO 2000 PSI 45 BBLS INTO DIESEL FLUSH WITH - 5 GPM LEAK. PUMPED ADDITIONAL 2 BBLS DIESEL AND WELL HELD 1500 PSI. SECURED WELL WITH 1500 PSI OAP. 04/04/03 1640/1750/1220 BLEED OA (POST OA DOWN SQUEEZE). OA FL NEAR SURFACE. BLEED OA FROM 1220 PSI TO 200 PSI IN 3.5 HOURS. STARTED AS GAS AND FLUID, PINCHED BLEED VALVE BACK AND BLED GAS FOR MOST OF THE BLEED OPERATION. POST OA FL @ 42'. MONITOR FOR 30 MINUTES. OAP INCREASED 20 PSI. FINAL WHP's 1640/1740/220. 04/05/03 T/IlO = 1640/1750/440 MONITOR WHP's (POST OA BLEED) OAP HAS INCREASED 220 PSI SINCE YESTERDAY. Fluids Pumped BBLS PRESSURE TEST LUBRICATOR W/DIESEL ( 2 TESTS) 182 DIESEL 182 TOTAL CANNEE: 0 5 2003 Page 1 TREE = 6" Mc EV OY WELLHEAD = McEVOY ACTUATOR = CA MF__.RO N KB. ELEV = 57' BF. FIEV = 26' KOP = 3854' Max Angle = 36 @ 5037' Datum MD = 9551' Datum TVD = 8800' SS I 13-3/8" CSG, 68#, L-80, ID = 12.415" Id 2977' Minimum ID = 3.725" @ 9122' 4-1/2" PARKER SWN NIPPLE 5-1/2" TBG, 17#, 13CR, 0.0232 bpf, ID = 4.892" Id 8907' ITOP OF 4-1/2'' TBG Id 8907' TOP OF 7" LNR Id 9013' ]4-1/2"'rBG, 12.6#, 13CR, 0.0152 bpf, ID = 3.958" Id 9134' I 9-5/8" CSG, 47#, L-80, ID = 8.681" Id 9267' PERFORATION SUMMARY RE]: LOG: SWS BHCS ON 05/07/92 ANGLE AT TOP PERF: 26 @ 9386' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPN/SQZ DATE 3-3/8" 4 9386-9504 O 05/23/92 3-3~8" 4 9514-9536 O 05/23/92 H 9862' 7" LNP~ 26#, 13CR, 0.0383 bpf, ID = 6.276" Id 9940' M-31 SAFETY NOTE: CHROME COMPLb-I-ION. BPV PROFILE IS NOT BP STANDARD. 1987' Id 5-1/2" OTIS SSSV LAND. NIP, ID=4.562" I GAS LIFT MANDRELS 8907' 8919' 8981' 9024' 9122' 9134' 9136' Id 5-1/2" X 4-1/2" XO I Id 4-1/2" PARKERSWS NIP, ID= 3.813" 9-5/8" X 4-1/2" BAKER SB-3 (LATCH) PKR, ID = 3.99" 4-1/2" PARKERSWS NIP, ID= 3.813" I 4-1/2" PARKER SWN NIP, ID= 3.725" I Id 4-1/2 -I-rL- WLEG I Id ELMD 'FI' LOGGED 05/22/91 I DATE REV BY COMMENTS DATE REV BY COMMENTS 05/14/92 ORIGINAL COMPLETION 02/27/01 SlS-Isl CONVERTEDTO CANVAS 03/14/01 SIS-MD FINAL 07/23/01 RN/TP CORRECTIONS 01/26/02 CO/KAK MAX ANGLE CORRECTION PRUDHOE BAY UNIT WELL: M-31 PERMIT No: 92-0320 APl No: 50-029-22256-00 Sec. 1, T11N, R12E BP Exploration (Alaska) 8CANNED 0 5 2003 ALASKA OIL AND GAS CONSERVATION COMMISSIO_~N. REPORT' SUNDRY WELL OPE ' TIONS 1. Operations performed: Operation shutdown... Stimulate × Plugging. Perforate .. Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchoracle, Alaska 99519-6612 4. Location of well at surface 2082' SNL. 606' WEL, SEC. 1, T11N, R12E At top of productive interval 182' NSL, 2016' WEL, SEC. 36, T12N, R12E At effective depth 4915'SNL, 2117' WEL, SEC. 36, T12N, R12E At total depth 398'NSL, 2135' WEL, SEC. 36, T12N. R12E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=57 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number M-31 (34-36-12-12) 9. Permit number/approval number 92-32 / 10. APl number 50-029-22256 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured 9945' true vertical 9211' Effective depth: measured 9862' true vertical 9136' Casing Length Size Structural -. Conductor 110' 20" Surface 2986' 13 3/8" Intermediate 9236' 9 5/8" Production -- Liner 927' Perforation depth: measured feet Plugs (measured) feet feet Junk (measured) feet Cemented 2085/425 c.f. Class "G" 2022/150 c.f. Class "G" 7" 290 c.f. Class "G" 9386'-9411 ', 9420'-9504', 9514'-9536' true vertical~ubsea 8647'-8670',8678'-8754',8763'-8782' Tubing (size, grade, and measured depth)5- 1/2"X 4 -1/2" 9135' Packers and SSSV (type and measured depth)Packer @ 8981' and SSSV @ 1988' Measured depth 141 3017 9267 9940-9013 True vertical depth BKB 141 3012 8597 9202-8369 RECEIVED ~',l ;~ 0 197)8 0ii & 'C~,~; Ooti~. C0~rflJs~lo~ 13. Stimulation or cement squeeze summar~ee Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 4610 4462 432 0 6630 5003 496 0 253 281 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations OilX Gas Suspended 17. I here~c~,th~e foxing is true 77r[ect to the best of my knowledge. Signed ~"-' (,~~,'~ ~ Title Technical Assistantlll Form 10-404 Rev'~06/15/88 Service Date // SUBMIT IN 61jISLICATE M-31 DESCRIPTION OF WORK COMPLETED Stimulation Operation 06/13/97 A Tubing Wash and Acid Stimulation Treatment was performed using the following fluids: SUMMARY Shutin well, pulled safety valve, tagged td @ 9,473. Pumped 38 bbls of 15% Hcl/10% Xylene followed by 172 bbls seawater for tubing wash. Treatment was 7.2 bpm @ 300 psi. Flowed well back recovering spent acid. Pumped 5% Hcl acid stimulation and shutdown at 55 bbls into stage due to pipe burst at surface. Secured well and comenced cleanup and notified authorities. Reconfigured pump job and completed pumping 230 bbls 5% Hcl followed by 336 bbls seawater. Treating pressure was 7.3 bpm @ 150 psi. Well was flowed back through Trico. Fluids Pumped BBLS. i Description 508 Sea Water 38 15% HCL/10% Xylene 230 5% HCL 776 Total 06/22/97 Stimulation Operation A Scale Inhibitor Treatment was performed using the following fluids: SUMMARY MIRU DOWELL CEMENT VAN. PT HARDLINE TO 3500 PSI. BH 100 BBL FSW SPEAR, 192 BBLS SI (10% B34 BY VOLUME), 305 BBLS FSW. OVER DISPLACED SI 83 BBLS INTO THE FORMATION. RDMO. TURNED WELL OVER TO PAD OPERATOR TO POP @ 2300 HRS. Fluids Pumped BBLS. Description ,.. 405 Fresh Sea Water 192 B34 Scale Inhibitor 597 Total STATE OF ALASKA ALAS.~-"OIL AND GAS CONSERVATION COMMISSIC"-' REPORT (.,F SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing_ Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2082' SNL, 606' WEL, SEC. 1, T11N, R12E At top of productive interval 182' NSL, 2016' WEL, SEC. 36, T12N, R12E At effective depth 4915' SNL, 2117' WEL, SEC. 36, T12N, R12E At total depth 398'NSL, 2135' WEL, SEC. 36, T12N, R12E Repair well Other 5. Type of Well: Development Exploratory Stratigraphic Service ORt¢tNAL 6. Datum elevation (DF or KB) KBE=57 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-31 (34-36-12-12) 9. Permit number/approval number 92-32 / 10. APl number 50- 029-22256 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 9945' feet 9211' feet Plugs (measured) Effective depth: measured true vertical 9862' feet 9136' feet Junk (measured) Casing Length Structural -- Conductor 110' Surface 2986' Intermediate 9236' Production -- Liner 927' Perforation depth: measured Size Cemented 20" '33/8" 9 5/8" 2085/425 c.f. Class "G" 2022/150 c.f. Class "G" 7" 290 c.f. Class "G" 9386'-9411 ', 9420'-9504', 9514'-9536' Measured depth 141 3017 9267 9940-9013 True vertical depth BKB 141 3012 8597 9202-8369 true vertical subsea 8647'-8670',8678'-8754',8763'-8782' RECEIVED Tubing (size, grade, and measured depth) 5- 1/2"X4 -1/2" 9135' Packers and SSSV (type and measured depth) Packer @ 8981' and SSSV @ 1988' JUN 1 4 i994 Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 4610j~. 4462 432 0 6630 5003 496 0 253 281 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby c,ertify that the fore. going is true and correct to the best of my knowledge. Signed ~,//.,..v~1/~''''(~/': '~,c~.,.-~,~3 Title Senior Technical Assistant, Form 10-4041Rev06/15/88 // ' SUBMIT IN DOPL(CA'r'E 2/24/93 WELL M-31(34-36-12-12) REPERF/FRAC The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9386'-9396'MD 9396'-9416'MD 9416'-9436'MD 3/03/93 fjh 6/10/94 Performed a Hydraulic Fracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST #1:75 BBLS DIESEL TO SET TREE SAVER 400 BBLS 208 GEL INJECTIVITY TEST DATA FRAC #1: 24 BBLS 408 GEL PREPAD TO ESTABLISH RATE 190 201 225 IFRAC: 116 36 7 12 17 21 25 28 335 212 BBLS 408 X-LINK GEL PAD BBLS 208 GEL DATA FRAC FLUSH BBLS DSL TO FREEZE PROTECT WELL 30 BBLS 408 GEL PREPAD TO ESTABLISH RATE BBLS 408 X-LINK GEL PAD Dirty 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 8 PPG 20g LINEAR GEL FLUSH RECEIVED ,jij~ 1 4 1994 ()it & ~as Cons. Commission .Anchorage PERMIT DATA 92-032 BHCS/GR 92-032 CNL 92-032 COMP 92-032 GR/CCL 92-032 PDI/SFL 92-032 PERF 92-032 PFC/GR 92-032 PROD 92-032 $STVD 92-032 407 92-032 DAILY WELL OP 92-032 SURVEY 92-032 SURVEY AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 92-032 5291 L 9302-9918 L 6900-9899 L 8992-9595 L 8800-9861 L 9302-9950 L 8995-9670 L 9300-9600 L 9300-9600 L 9302-9950 R COMP DATE: 05/24/92 R 04/24/92-05/14/92 R 0-9221, MWD R 0-9945, GCT T 6890-10010, OH-BCS Page: 1 Date: 04/11/94 RUN DATE_RECVD 1 05/18/92 1 05/18/92 1 06/11/92 1 06/11/92 1 05/18/92 1 06/11/92 1 03/10/93 1 07/14/92 1 05/18/92 07/09/92 07/09/92 07/09/92 07/09/92 1 06/11/92 Are dry ditch samples required? yes no And received? yes no Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial yes no Comments r .. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03-03-93 T# 84406 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-07~CH -06~CH M-31~CH N-14~CH N-16~CH - S-33~CH X-14A~..~H 02/23/93 REF#124752 02/22/93 REF#124751 02/23/93 REF#124673 02/24/93 REF#124674 02/26/93 REF#124801 02/25/93 REF#124675 . 02/25/93 REF#124754 02/24/93 REF#124753 PRODUCTION LOGGING SERV ATLAS PRODUCTION LOGGING SERV ATLAS COLLAR LOG (CHEMICAL CU ATLAS PFC GAMMA RAY (PERFORAT ATLAS PFC GAMMA RAY (PERFORAT ATLAS PRODUCTION LOGGING SERV ATLAS PRODUCTION LOGGING SERV ATLAS PFC/CCL (PERFORATION RE ATLAS Information Services Well Records UAR 7 0 199 A/aska 011 & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/02/92 T# 83667 BP CASED HOLE FINALS · . . Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. B-31 ~1-~ INJ F-39 ~-I~ TEMP M-29 ~-% INJ M-30 ~-~ PROD-F M-31 7>-~'PROD-F M-32~~ PROD-F 06/18/92 #t 06/20/92 #1 06/22/92 #1 06/18/92 #1 06/20/92 #1 06/18/92 #! 9200 00- 9753.00 CAMCO 5 " 3000 00-13404.00 CAMCO 2 " 9550 00- 9800.00 CAMCO 5 " 3050 00-11150.00 CAMCO 2/5" 9300 00- 9600.00 CAMCO 5 " 2900 00- 9100.00 CAMCO 2/5" Information Control Well Records Adrian J. Martin RECEIVED JUL 1 4 1992 Alaska Oil & Gas Cons. Commission Anchorage "'-'" STATE OF ALASKA -" 0 ~ i ~ I I 1~1 ~ ALASKA oil AND GAS CONSERVATION Cu,~i, MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SI. JSPEt, I~D [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 92-32 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22256 4. Location of well at surface 9. Unit or Lease Name I Prudhoe Bay. Unit At Top Producing Interval 10. Well Number M-31 (34-36-12-12) 182' NSL, 2016' WEL, SEC. 36, T12N, R12E 1'~. Field and Pool At Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 398' NSL, 2135' WEL, SEC. 36, T12N, R12E , 5. Elevation in feet (indicate KB, DF, etc.) is. Lease Designation and Serial No. KBE = 57' I ADL 28257 12. Date SPudded 13. Da~e T.D. Reached 14. Date Comp., Susp. or Aband. J15. Water Depth, il offshore J16. No. of CompletiOns 4/24/92 5/8/92 5/24/92I N/Aeet MSL I One 17. Total Depth (MD+TVD) i18. Plug Back Depth (MD+TVD 19. Directional Survey p. Depth where SSSV set }21. Thickness of Permafrost 9945'MD/9211'TVD 9862'MD/9136'TVD YES [] t,D E!! 1988feet MD ! 1900' 22. Type Electric or Other Logs Run DIL/BHC/CNL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' Cond. Weld Surface 110' 30" 13-3/8' 68# L-80 Surface 3017' 17-1/2" 2085 cu ft Class "G"/425 cu fl Class "G" 9-5/8' 47# L-80 Surface 9267' 12-1/4" 2022 cu fi Class "G"/150 cu f Class "G" 7' 26# 13-CR 9013' 9940' 8-1/2" 290 cu ft Class "G" 24'. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBlNG RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI Gun Diameter 3.375" 4spf 5-1/2"X4-1/2" 9135' 8981' MD TVD 9386'-9411' 8647'-8670' 9420'-9504' 8678'-8754' 126. ACID, FRACTURE, CEMENT SQUEEZe. ETC. 9514'-9536' 8763'-8782' . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED Freeze protected w/130 BBL's. Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/7/92 I FiowinE Date of-Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ I Fi~)w Tubing Casing Pressure DALCULATED ,OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED d U L - 9 1992 Alaska 0il & Gas Cons, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ZI9. ' 30. ~OGIC MARKERS _ .~MATION TESTS ,, NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Shublik 9284' 8556' Top Sadlerochit 9385' 8647' . ., 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~ ~~- TitleWorkoverEnoineerSuoervisor Date INSTRUCTIONS General: This form is designed fOr submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this fm:m and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple' completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. --. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 - 9 1992 Alaska Oil & Gas Cons, ,CO.~ BP/AAI SHARED SERVICE DAILY OPERATIONS JUL - 9 199' /~l~k~l~;& Gas Cons. CommFJ~O~ PAGE WELL: M-31 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-22256 PERMIT: APPROVAL: ACCEPT: 04/24/92 04:04 SPUD: 04/25/92 05:04 RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NONE 04/24/92 ( 1) TD: 0' ( 0) TURNKEY RIG MOVE FROM Z-19 TO M-31. MW: 0.0 VIS: 0 04/25/92 (2) TD: 482' ( 482) 04/26/92 ( 3) TD: 2600' (2118) 04/27/92 ( 4) TD: 3030'( 430) 04/28/92 ( 5) TD: 3030'( 0) 04/29/92 (6) TD: 3500' ( 470) 04/30/92 (7) TD: 5059' (1559) 05/0Z/92 ( 8) TD: 6045'( 986) SURVEY MW: 8.8 VIS:200 MIRU RIG 28E. MIX SPUD MUD. DRILL ICE FROM 44 TO GRAVEL AT 110'o DRILL TO 482' CIRCULATE. GYRO SS SURVEY. DRILLING MW: 9.5 VIS:230 DRILL TO 1022'. GYRO SURVEY. DRILL TO 1500. GYRO SURVEY. DRILL TO 2008. SURVEY. DRILL TO 2517. SURVEY. DRILLING TO 2600. CIRCULATE SWEEP MW: 9.6 VIS:142 DRILL TO 2778'. CIRCULATE. DRILL TO 2838' RUN GYRO. DRILL TO 2867' CBU. CHANGE BIT & RIH_ DRILL TO 3030'. PUMP SWEEP & CIRCULATE. GYRO SURVEY. POOH TO RU 13-3/8 CASING. RUN 13-3/8 CASING. HIT TIGHT HOLE AT 2000'. CIRCULATE AND WORK PIPE & BROKE THROUGH BRIDGE. PUMP SWEEP. REPAIR HYDRILL MW: 8.8 VIS: 28 RUN 13-3/8 CASING. WORK THROUGH TIGHT HOLE TO 2350' CEMENT 13-3/8 CASING. RECIPROCATE PIPLE. N/U BOPE. CBU. DRILLING AT 3500' MW: 8.8 VIS: 32 CHANGE PISTON IN HYDRIL. N/U RISER & FLOWLINE. TEST BOPE. P/U, M/U BHA. RIH. CIRC. TEST CASING. DRILLED TO 3040' CIRC. RUN GRYO. DRILLED TO 3184'. RUN GYRO. DRILLED TO 3500'. TRIP FOR BIT #4 MW: 9.7 VIS: 37 DRILLED AND SURVEYED TO 4771'. SHORT TRIP. DRILLED AND SURVEYED TO 5059'. CIRC. POOH FRO BIT #4. DRILLING AT. 6045 MW: 9.7 VIS: 39 POOH. P/U BIT#4. RIH. DRILLED AND SURVEYED TO 6045'. 05/02/92 (9) TD: 6900'( 855) DRILLING AT 6900 MW: 9.8 VIS: 41 DRILLED AND SURVEYED TO 6592'-- CBU. TRIP FOR BIT #5. DRILLED TO 6900' WELL : M-31 OPERATION: RIG : NABORS 28E PAGE: 2 05/03/92 (10) TD: 7883' ( 983) DRLG.. MW: 9.8 VIS: 37 DRLG F/ 6900'-6941'. CBU. POOH. RIH. WASH 50' TO BTM. DRLG F/ 6941'-7883'. 05/04/92 (11) TD: 9125' (1242) DRLG. MW: 9.8 VIS: 39 DRLG F/ 7883'-8329'. SHORT TRIP TO 6930' DRLG F/ 8329'-9125'. 05/05/92 (12) TD: 9295' ( 170) RIH W/ 9-5/8" CSG. MW: 9.8 VIS: 41 DRLG F/ 9195'-9295' CBU. SHORT TRIP TO 6725' CBU. POOH. L/D BHA. TEST BOPE. RIH W/ 9-5/8" CSG. 05/06/92 (13) TD: 9295' ( 0) N/U BOPE. MW: 8.8 VIS: 29 RIH W/ 9-5/8" CSG WASH & WORK CSG TO 9248'. N/U LAND JT. WASH & WORK CSG T6 9261'. CIRC. CMT CSG W/ 730 SX LEAD CMT, 130 SX TAIL CMT. DISP W/ 676 BBLS MUD. NO BUMP PLUG. N/D BOPE. SET SLIPS. CUT CSG. INSTALL PACKOFF. N/U BOPE. 05/07/92 (14) TD: 9760' ( 465) DRILLING MW: 8.8 VIS: 40 ING. MUD INTO ANNULUS. TEST BOPE. M/U 8-1/2 BAH. TIH. TAG CEMENT AT 9170'. CBU. PRESSURE TEST 9-5/8 CASING. DRILL CEMENT TO 9258'. DRILL TO 9760' 05/08/92 (15) TD: 9945' ( 185) CIRCULATE MW: 8.8 VIS: 40 DRILL TO 9945'. CBU. TRIP TO 9-5/8 SHOE. CBU. POOH TO LOG. RUN DIL/BHC/CNL/GR TO 9958'. TIH. CIRCULATE. 05/09/92 (16) TD: 9945 PB: 9945 CHANGE RAMS. MW: 8.8 WBM CIRC. POOH. TEST BOPE. R/U CSG TOOLS. RIH W/ 7" NCSS 13 CR CSG. CIRC. PUMP 25 BBLS WATER, 50 BBLS DOWELL MUD PUSH. DISP W/ MUD. BUMP PLUG W/ 3000 PSI. RELEASE F/ HGR. 05/10/92 (17) TD: 9945 PB: 9945 SPEAR 9-5/8" CSG. MW: 8.8 WBM RIH W/ HOWCO RBP. SET @ 2000' DROP[ 20' SNMD. N/U BOPE. SPEAR 9-5/8" SLIPS. PULL TO FLOOR. PULL SLIPS, CSG TO FLOOR. L/D CSG. N/D BOPE. RIH W/ BACKOFF TOOL. ATRTEP TO PULL PKR. RESET BACKOFF TOOL. BACKOFF CSG @ 478'. POOH. L/D BHA. RIH W/ SPEAR. 05/11/92 (18) TD: 9945 PB: 9945 DRLG CMT. MW: 8.8 WBM POOH. L/D SPEAR, CSG. RIH W/ 12 JTS 9-5/8" CSG. M/U ON CSG @ 478'. TEST CSG. SET SLIPS. CUT CSG. N/U BOPE. TEST BOPE. RIH W/ GLOBE BASKET. CUT 5' DRY CORE. POOH. L/D SAME. NO JUNK. RIH W/ HOWCO OVERSHOT TO 2000'_ WASH 20' SAND. REV CIRC. RELEASE RBP. CBU. POOH. L~D TOOLS. RIH. TAG CMT STRINGER @ 8640'. DRLG CMT F/ 8640'-8700'. WELL : M-31 OPERATION: RIG : NABORS 28E PAGE: 3 05/12/92 (19) TD: 9945 PB: 9945 05/13/92 (20) TD: 9945 PB: 9862 05/14/92 (21) TD: 9945 PB: 9862 M/U TAIL ASS'Y,PKR. MW: 8.6 NaC1 DRLG CMT F/ 8640'-9006'. CIRC. TEST CSG. POOH. L/D BHA. RIH. DRLG CMT F/ 9837'-9862'. CIRC. TEST CSG, LNR. CLEAN PITS. PUMP 200 BBLS WATER, 80 BBLS DIRT MAG, 80 BBLS SWEEP, DISP W/ SEAWATER. POOH. L/D BHA. RIH W/ 4-1/2" TAIL ASS'Y & BAKER 'D' PKR. RIH W/5-1/2 TUBING MW: 8.5 Seawater P/U & M/U TAIL PIPE ASSEMBLY. RIH W/TAILPIPE ASSY ON DP. SET PACKER AT 8982'. POOH L/D DP. R/U & RIH. W/5-1/2 COMPLETION. RIH. FREEZE PROTECTED WITH DIESEL 13-3/8 X 9-5/8 RIG RELEASED/WELL SECURED MW: 8.5 Seawater RIH W/5-1/2 COMPLETION ASSY. INSTALL TUBING HANGER. CIRC. FREEZE PROTECT W/130 BBL DIESEL. LAND TUBING. TEST TUBING. SET BPV. ND BOPE. N/U TREE. RIG RELEASED 0100 HRS. 5/14/92. SIGNATURE: (drilling superintendent) DATE: RECEIVED d U L - 9 199: Alaska.Oil & Gas cons. commission Anchora~ PAGE 1 SPERRY-SUN DRILLING SERVTCES BP EXPLORATION INC PRUDHOE BAY/M-31 500292225600 NORTH SLOPE COMPUTATION DATE: 5/ 5/92 DATE OF SURVEY: 05/04/92 MWD SURVEY JOB NUMBER: AK-MW-20026 KELLY BUSHING ELEV. = 57,00 FT. OPERATOR: BP EXPLORATION INC TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DLS TOTAL RECTANGULAR COORDINATES DG/IO0 NORTH/SOUTH EAST/WEST VERT, SECT, 0 .00 478 478.00 997 997.00 1475 1474,94 1983 1982.83 -57,00 0 0 N ,00 E 421,.00 0 0 N .00 E 940,00 0 15 N 20,00 W 1417,94 1 15 N 1,00 W 1925,83 1 6 N 59.00 E ,00 ,OON .OOE .00 ,00 ,OON ,OOE .00 ,05 1,06N ,39W 1,11 ,21 7.26N ,83W 6,68 ,23 15,31N 3,25E 11,55 2492 2491.77 2813 2812,77 2998 2997.77 3078 3077,76 3269 3268,76 2434,77 0 30 S 53.00 E 2755,77 0 15 S 13.00 E 2940.77 0 15 S 40,00 W 3020,76 0 24 N 6,30 E 3211,76 0 30 N 15,90 E ,20 16.49N 9,21E ,11 14.96N 10.49E ,12 14,26N 10,32E ,78 14,40N 10.24E ,07 15,87N 10.54E 9.55 7,59 7,07 7,23 8.34 3402 3401,75 3492 3491,73 3682 3680.87 3873 3869.28 4059 4050.42 3344,75 0 30 N 32,60 E 3434,73 1 54 N 11,50 W 3623,87 8 23 N 33,60 W 3812,28 10 23 N 26,50 W 3993,42 15 41 N 33.90 .~ .11 16,92N 11.01E 1,76 18,71N 10,92E 3,51 33,37N 2,61E 1,21 60.42N 12.81W 2,98 96.36N 34,35W 9.00 10,59 27,45 58.58 100,48 4~4 4234 64 4444 4407.71 4635 4576,59 4825 4740.95 5111 4981.04 4177.64 22 23 N 30.70 W 4350,71 26 17 N 32,30 W 4519,59 29' 23 N 27,20 W 4683,95 30 47 N 29,10 W 4924,04 35 0 N 31,20 W 3,48 150.27N 68.07W 164.04 2,08 217,00N 109,07W 242.34 2,05 294,49N 153.12W 331.48 ,89 378.48N 198,10W 426.67 1.52 512,68N 276,23W 581.96 5364 5192,60 5555 5356.i4 5747 5521,74 5939 5689.32 6066 5801,14 5135.60 31 30 N 33.40 N 5299.14 30 42 N 33.20 W 5464.74 30 6 N 33.70 W 5632.32 28 17 N 33.90 N 5744,14 28 17 N 33,20 W 1,46 629.96N 350.23W 720,57 ,42 712,42N 404.40W 819.10 ,34 793,48N 457.95W 916.12 ,94 871.31N 510.04W 1009.62 .26 921.49N 543.32W 1069.74 6319 6023,05 6666 6327.27 6858 6496,64 7016 6636,14 7270 6859,36 5966.05 29 6 N 32,20 W 6270,27 28 23 N 31,60 W 6439,64 27 47 N 31,80 W 6579.14 28 12 N 30,80 W 6802,36 28 47 N 29.10 W ,37 1023,73N 608,94W 1191,13 .22 1165,42N 697,14W 1357,98 ,32 1242,36N 744.66W 1448,39 ,39 1305,74N 783.19W 1522.55 ,40 1410,75N 843,68W 1643,73 7491 7052.74 7778 7303,27 8096 7580.18 84t3 7856,76 8731 8136,34 6995.74 29 6 N 29.00 W 7246.27 29 17 N 31,50 W 7523.18 29 36 N 32.80 W 7799.76 28 53 N 28,00 W 8079.34 28 0 N 2.9,00 W .14 1504,27N 895.02W 1750.68 .43 1625,18N 966.15W 1890.66 .22 1757,55N 1049,35W 2046.93 ,'77 1890.99N 1127,72W 2201,68 .32 2024.12N 1199.99W 2353,07 MICROFILMED RECEIVED UP~NY-SUN DRILLTNG SERVICES ~'""'". ANCHORAGE ALASKA ~ PAGE 2 BP EXPLORATION INC PRUDHOE BAY/M-31 500292225600 NORTH SLOPE COMPUTATION DATE' / 5/92 DATE OF SURVEY: 05/04/92 MWD SURVEY JOB NUMBER: AK-MW-20026 KELLY BUSHING ELEV, = 57,00 OPERATOR: BP EXPLORATION INC FT, TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE' DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST VERT, SECT. 9049 8419,03 8362,03 26 30 N 27,90 W ,50 2152,11N 1269,37W 9221 8573,48 8516',48 25 42 N 27,20 W ,50 2219,19N 1304,38W THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. 2498,57 2574,14 HORIZONTAL DISPLACEMENT = 2574,14 FEET AT NORTH 30 DEG, 26 MiN, WES'T AT MD = 9221 VERTICAL SECTION RELATIVE 70 WELL HEAD VERTICAL SECTION COMPUTED ALONG 329,55 DEG, SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION ZNC PRUDHOE BAY/M-31 500292225600 NORTH SLOPE COMPUTATION DATE: 5/ 5/'92 BATE OF SURVEY' 05/04/92 JOB NUMBER' AK-MW-20026 KELLY BUSHING ELEV. = 57.00 OPERATOR' BP EXPLORATION INC FT, INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -57.00 .00 N- ,00 E 1000 1000.00 943,00 1.08 N .39 W 2000 1999.83 1942.83 15,48 N 3.53 E 3000 2999.77 2942.77 14.25 N 10.31 E 4000 3993.39 3936.39 83.69 N 26.10 N .00 .00 .00 .17 .17 .23 .06 6.61 6.37 5000 4889.22 4832.22 459.13 N 244,28 6000 5743.03 5686.03 895.32 N 526,17 7000 6622.04 6565.04 1299,25 N 779.32 8000 7496.71 7439,71 1717,69 N 1023.66 9000 8375.17 8318.17 2132,79 N 1259.14 110,78 104.17 256.97 146.19 377.96 120.99 503 29 125 ~ 624.83 121.53 9221 8573.48 8516.48 2219,19 N 1304.38 N 647.52 22.69 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRTLLTNG SERVT'CES ANCHORAGE ALASKA PAGE BP EXPLORATZON ZNC PRUBHOE BAY/M-31 500292225600 NORTH SLOPE COMPUTATZON DATE: 5/ 5/92 DATE OF SURVEY' 05/'04/92 JOB NUMBER' AK-MW-20026 KELLY BUSHZNG ELEV, = 57,00 OPERATOR' BP EXPLORATZON ZNC FT. ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNAT NORTH/SOUTH EAST/WE ES MD-¥VD VERYZCAL ST DZFFERENCE CORRECTZON 0 .00 -57,00 57 57,00 ,00 157 157,00 100.00 257 257,00 200,00 357 357,00 300,00 ,00 N- ,00 E ,00 ,00 N ,00 E .00 ,00 ,00 N ,00 E ,00 ,00 ,00 N ,00 E .00 ,00 ,00 N ,00 E ,00 ,00 457 457,00 4OO 557 557.00 500 657 657.00 600 757 757.00 700 857 857,00 800 · 00 ,00 N ,00 ,00 ,00 N .00 ,00 ,00 N ,00 .00 ,08 N ,03 .00 ,49 N .18 E .00 .00 E ,00 ,00 E ,00 .00 W ,00 ,00 W .00 .00 957 957.00 900 1057 1057,00 1000 1157 1157.00 1100 1257 1257,00 1200 1357 1357.00 1300 ,00 .90 N .33 ,00 1,31 N ,48 ,00 1,72 N ,63 .00 2,50 N ,75 ,00 4,68 N ,79 W .00 .00 W .00 .00 W .00 .00 W .01 .01 W .03 .02 1457 1457.00 1400 1557 1557.00 1500 1657 1657.00 1600 '1757 1757.00 1'700 1857 1857.00 1800 .00 ,00 ,00 ,00 ,00 6,87 N .83 W .06 ,02 9.05 N .87 W .08 .02 11.23 N .90 W .11 .02 13.08 N .47 W .13 .02 14.06 N 1.18 E .15 .02 1957 1957.00 1900 2057 2057.00 2000 2157 2157,00 2100 2257 2257.00 2200 2357 2357.00 2300 .00 15.05 N 2.82 .00 16.04 N 4.47 .00 17.03 N 6.11 .00 17.72 N 7.57 .00 17.20 N 8.27 E .16 .02 E , 18 ,02 E .2O .O2 E ,22 ,02 E ,22 ,00 2457 2457,00 2400 2557 2557,00 2500 2657 2657,00 2600 2757 2757.00 2700 2857 2857.00 2800 . 0'0 ,00 ,00 ,00 .00 16.67 N 8.97 16.15 N 9.66 15.63 N 10.32 15.20 N 10.43 14,77 N 10,53 E .22 .00 E ,23 ,00 E ,23 ,00 E ,23 ,00 E ,23 ,00 2957 2957,00 2900.00 3057 3057.00 3000.00 3157 3157.00 3100.00 3257 3257,00 3200.00 3357 3357.00 3300.00 14.40 N 10.43 14.26 N 10.22 14.95 N 10.30 15.77 N 10.51 16.59 N 10,80 E .23 ,00 E ,24 .,00 E ,24 . O0 E .24 , O0 E ,25 ,00 SPERRY-SUN DRZLLZNG SERVZCES /~ ANCHORAGE ALASKA PAGE 5 BP EXPLORATZON ZNC PRUDHOE BAY/H-31 500292225600 NORTH SLOPE COHPUTATZON DATE: 5/ 5/92 DATE OF SURVEY: 05/04/92 JOB NUNBER: AK-MW-20026 KELLY BUSHZNG ELEV. = 57.00 FT, OPERATOR: BP EXPLORATZON ZNC ZNTERPOLATED VALUES FOR EVEN 10© FEET OF SUB-SEA DEPTH TRUE SUB-SEA NEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNATES NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON 3457 3457.00 3400.00 3557 3557.00 3500.00 3657 3657.00 3600.00 3758 3757.00 3700,00 3860 3857.00 3800.00 17.60 N 11.14 E .26 .01 21.85 N 9.65 E .37 .11 30.58 N 4,43 E .90 ,53 42,73 N 3,62 N 1.96 1,06 58.40 N 11.80 W 3.52 1,56 3962 3957.00 3900.00 4065 4057.00 4000,00 4170 4157,00 4100.00 4278 4257.00 4200.00 4387 4357.00 4300,00 4499 4457.00 4400.00 4612 4557.00 4500.00 4727 4657.00 4600.00 4843 4757.00 4700.00 4961 4857,00 4800,00 76.27 N 21.56 W 5.58 2.06 97.93 N 35.40 W 8.85 3.26 124.85 N 52.67 W 13.86 5.01 158.29 N 72,86 W 21.23 7,38 196,32 N 96.10 W 30',72 9.49 238.18 N 122.04 284.79 N 148.07 334.86 N .'173.93 386.88 N 202.79 441.01 N 233.69 42.20 11.47 55.57 13.37 70.35 14.79 86.71 16.36 104.55 17.84 5081 4957.00 4900.00 5203 5057.00 5000.00 5322 5157.00 5100.00 '5439 5257.00 5200,00 5556 5357,00 5300.00 498.38 N 267.61 556.92 N 303.42 611.50 N 338.15 662.91 N 371.96 712.85 N 404.68 124.73 20.18 146.01 21.28 165,12 19.11 182.54 17.42 199.00 16.47 5672 5457.00 5400 5787 5557,00 5500 5902 5657.00 5600 6015 5757,00 5700 6129 5857.00 5800 6243 5957.00 5900 6357 6057.00 6000 6472 6157.00 6100 6586 6257.00 6200 6699 6357.00 6300 6813 6457.00 6926 6557.00 7O39 6657,OO 7153 6757.00 7267 6857.00 64OO 6500 6600 6700 6800 .00 .00 .00 .00 .00 .o0 .00 .00 .00 .00 .00 .00 .00 .00 .00 762.26 N 437.12 810.49 N 469.29 856.87 N 500.34 901.61 N 530.30 946.66 N 559,79 215.17 16.17 230.76 15.59 245.29 14.54 258.87 13.57 272.44 13.57 992.62 N 589.35 W 286,40 13.96 1039.72 N 619,01 W 300.85 14,45 1086.82 N 648,67 W 315.30 14.45 1133,06 N 677.24 W 329.11 13.82 1179,11 N 705.57 W 342.80 13,68 1224.60 N 733.65 1269.42 N 761.43 1315.35 N 788.92 1361,60 N 816,31 1409,62 N 843,05 356,19 13,39 369.24 13.'05 382.67 13.42 396,20 13,53 410.31 14.11 SPERRY-SUN DRILLING SERVICES_. "*~' ANCHORAGE ALASKA PAGE 6 BP EXPLORATION INC PRUDHOE BAY/M-31 500292225600 NORTH SLOPE COMPUTATION DATE: 5/ 5/92 TNTERPOLATED VALUES FOR EVEN 100 DATE OF SURVEY: 05/04/92 JOB NUMBER: AK-MW-20026 KELLY BUSHING ELEV. = 57,00 OPERATOR: BP EXPLORATION INC FEET OF SUB-SEA DEPTH FT, TRUE SUB-SEA MEASD VERT]'CAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7381 6957.00 6900.00 1457.66 N 869.79 W 424.43 14.12 7495 7057.00 7000.00 1506,34 N 896.77 W 438.87 14.44 7610 7157,00 7100.00 1555.02 N 923.76 W 453.32 14.45 7724 7257,00 7200.00 1603,05 N 952.58 W 467,94 14.62 7839 7357.00 7300.00 1650,89 N 981,90 W 482,61 14.67 7954 7457,00 7400,00 1698,73 N 1011,44 W 497,33 14,72 8069 7557.00 7500,00 1746,48 N 1042,22 W 512,34 15.01 8184 7657,00 7600,00 1794,23 N 1072.99 W 527.35 15,01 8299 7757,00 7700,00 1842.37 N 1101,87 W 542,05 14,70 8413 7857,00 7800,00 1891,11 N 1127.79 W 556,28 14.23 8527 7957,00 7900,00 1939.85 N 1153,70 W 570.50 14.23 8641 8057,00 8000,00 1987,22 N 1179.53 W 584,14 13.53 8754 8157.00 8100,00 2033,73 N '1205.31 W 597.40 13.26 8867 8257,00 8200,00 2080,23 N 1231,09 W 610.65 13,26 8979 8357.00 8300,00 2124,78 N 1254,90 W 622.69 12.04 9091 8457.00 8400,00 2168,84 N 1278,23 W 634.43 11.74 9202 8557,00 8500.00 2212,14 N 1300.75 W 645,71 11,28 9221 8573.48 8516,48 2219,19 N 1304,38 W 647.52 1.81 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS OR ~L , SUB- SURFACE DIRECTIONAL SURVEY UIDANCE F~ ONTINUOUS F~ OOL Company BP EXPLORATION Well Name M-31 (34-36-12-12)(2082'SNL,606'WEL,SEC 1,T11N,R12E) Field/Location PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. Date 92325 22-MAY- 1992 Loqcled By: Computed By: JEFF FORMICA R. KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION M-31 (34-36-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 22-MAV-1992 ENGINEER: JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- Average~ deviation and azimuth LINEAR HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH 31 DEG 0 MIN WEST COMPUTATION DATE: 2-JUN-92 PAGE BP EXPLORATION M-31 (34-36-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 22-MAY-1992 KELLY BUSHING ELEVATION: 57.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE .MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH -DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -57.00 0 0 N 0 0 E 0.00 0.00 100.00 100.00 43.00 0 13 N 50 38 E -0.06 0.71 200,00 200,00 143,00 0 6 S 33 34 W 0,12 0,41 300,00 300,00 243,00 0 7 N 10 46 W 0,14 0,23 400,00 400,00 343,00 0 9 S 26 15 W 0,25 0,29 500,00 500,00 443,00 0 7 N 42 39 W 0,24 0,21 600,00 600,00 543,00 0 5 S 24 40 W 0,30 0.12 700,00 700,00 643.00 0 6 S 88 46 W 0,40 0,15 800,00 800,00 743.08 0 5 N 55 42 W 0,45 0.07 900,00 900,00 843,0~ 0 9 N 4t 17 ~ 0.63 0,12 0 O0 N 0 03 N 0 18 N 0 22 N 023 N 0 20 N 0 17 N 0 19 ~ 0 16 N 0 27 ~ 0.00 E 0,00 N 0 0 E 0,16 E 0,16 N 79 12 E 0,06 E 0,19 N 18 28 E 0,09 E 0,24 N 21 10 E 0,10 W 0,25 N 24 2 W 0,13 W 0,24 N 32 6 iN 0,30 W 0,35 N 59 56 iN 0,45 W 0,49 N 66 59 0,60 iN 0,62 0.78 ~ 0,82 N 71 12 1000,00 1000,00 943,00 0 18 N 16 19 W 1,04 0,00 1100,00 1099,99 1042,99 0 35 N 8 38 E 1,64 0.59 1200,00 1199,99 1142,99 0 49 N 8 8 E 2,61 0,08 1300,00 1299,98 1242,98 0 56 N 8 39 E 3,75 0,36 1400,00 1399,96 1342,96 1 5 N 7 42 E 5,13 0,09 1500,00 1499,94 1442.94 1 24 N 18 10 E 6,69 0,89 1600,00 1599,90 1542,90 1 35 N 33 24 E 8.19 0,67 1700,00 1699,87 1642,87 1 12 N 38 36 E 9,07 0,08 1800,00 1799,85 1742,85 1 5 N 40 44 E 9,72 0,77 1900,00 1899,84 1842,84 0 54 N 45 59 E 10,17 0,08 0,66 N 1,35 N 2,62 N 4,08 N 5,84 N 7,88 N 10,40 N 12,24 N 13,78 N 15,00 N 0,92 W 1, 13 N 54 39 W 0,94 W 1,64 N 34 50 iN 0,71 iN 2,72 N 15 8 W 0,50 W 4.11 N 6 56 iN 0,25 W 5,84 N 2 26 W 0,12 E 7,88 N 0 54 E 1,41 E 10,49 N 7 44 E 2,76 E 12.55 N 12 44 E 4,07 E 14.37 N 16 28 E 5.23 E 15,89 N 19 13 E 2000,00 1999,83 1942,83 0 37 N 63 24 E 2100,00 2099 82 2042,82 0 37 N 86 25 E 2200,00 2199 2300,00 2299 2400,00 2399 2500,00 2499 2600,00 2599 2700,00 2699 2800,00 2799 2900,00 2899 82 2142,82 0 40 N 82 18 E 8t 2242.81 0 38 S 89 51 E BO 2342.80 0 38 S 84 41 E 80 2442,80 0 25 S 76 39 E 79 2542,79 0 27 S 66 30 E 79 2642,79 0 21 S 58 41 E 79 2742,79 0 17 S 54 55 E 79 2842.79 0 6 S 16 4 W 10 4O 10 07 9 58 9 08 8 39 7 8O 7 21 6 61 6 06 5 79 1,13 0 O0 0 O0 0 05 010 0 38 0 O0 0 23 0 17 0 34 15,95 N 6,36 E 17,17 N 21 44 E 16,15 N 7,32 E 17.73 N 24 24 E 16,27 N 8,47 E 18,35 N 27 31 E 16,35 N 9,58 E 18.95 N 30 23 E 16,25 N 10,76 E 19.49 N 33 31 E 16,15 N 11 ,7.~ E 19.96 N 36 1 E 15,87 N 12,40 E 20.14 N 38 1 E 15,57 N 13.07 E 20.33 N 40 2 E 15,21 N 13,55 E 20,37 N 41 42 E 15,01 N 13,74 E 20.35 N 42 28 E 3000,00 2999 79 2942,79 0 7 S 65 57 E 3100,00 3099 79 3042,79 0 6 N 4 48 W 3200,00 3199 79 3142,79 0 27 N 31 25 E 3300.00 3299 79 3242.79 0 23 N 13 33 E 3400.00 3399 78 3342,78 0 28 N 27 44 E 3500,00 3499 77 3442,77 2 5 N 10 32 W 3600,00 3599,33 3542,33 7 35 N 32 42 W 3700,00 3698,28 3641,28 8 32 N 33 14 W 3800,00 3797.09 3740.09 9 20 N 32 33 W 3900.00 3895,58 3838,58 10 39 N 30 53 W 5,53 5,58 5,83 6,29 6,71 7,83 16,67 31,11 46,50 63,78 0,43 0,31 14,82 N 13 0.00 15,25 N 14 0,00 15,96 N 14 0,38 16,59 N 14 6,65 18,02 N 14 3,56 25,85 N 10 0,21 37,93 N 2 1,33 50,85 N 5 1,81 65,58 N 14 14.77 N 13 84 E 20.24 N 43 9 E 82 E 20,27 N 43 1 E 07 E 20,75 N 42 41 E 35 E 21,46 N 41 58 E 57 E 22 08 N 41 18 E 79 E 23 32 N 39 22 E 66 E 27 96 N 22 24 E 73 E 38 03 N 4 7 E 65 iN 51 16 N 6 21 iN 70 iN 67 20 N 12 38 iN BP EXPLORATZON M-31 (34-36-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 2-JUN-92 PAGE 2 DATE OF SURVEY: 22-MAY-1992 KELLY BUSHING ELEVATION: 57.00 FT ENGINEER= JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. .AZIMUTH DEPTH OEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3993.35 3936.35 13 39 N 35 0 W 84.70 4100.00 4089.79 4032.79 17 4 N 34 43 W 111.00 4200.00 4184.20 4127.20 21 21 N 33 12 W 143.87 4300.00 4276.43 4219.43 23 59 N 33 20 W 182 4i 4400.00 4367.09 4310.09 25 51 N 33 54 W 224 56 4500,00 4456.46 4399.46 27 29 N 32 52 W 269 36 4600.00 4544..44 4487.44 29 17 N 29 56 W 316 87 4700.00 4631.17 4574.17 30 19 N 30 22 W 366 6~ 4800.00 4717.27 4660.27 30 55 N 30 47 W 417 54 4900.00 4802.64 4745.64 31 53 N 30 44 W 469 57 3,43 3,15 3,73 2,41 1 ,65 2.14 1 ,55 0,7t~. 0,72 1 .4~ 83.14 N 26.09 W 87 14 N 17 26 W 104,68 N 41,31 W 112 131,94 N 59,66 W 144 164,3~ N 80,71 W 183 199.43 N 104.09 W 224 236.80 N 128,90 W 269 277.41 N 153,56 W 317 320,51 N 178.45 W 366 364,28 N 204,38 W 417 409.04 N 230.97 W 469 54 N 21 32 W 80 N 24 20 W 06 N 26 10 W 96 N 27 34 W 61 N 28 34 W O7 N 28 58 W 84 N 29 6 ~ 69 N 29 18 ~' 74 N 29 27 W 5000,00 4886,48 4829.48 34 34 N 31 49 W 524,06 5100,00 4968,13 4911.13 35 13 N 32 50 W 581,78 5200,00 5049,76 4992,76 35 31 N 33 13 W 639,50 5300.00 5131.85 5074.85 33 32 N 33 59 W 696.55 5400.00 5216.43 5159.43 31 37 N 35 4 W 749 76 5500.00 5301o29 5244.29 32 13 N 35 1 W 802 53 5600.00 5386.89 5329.89 30 2 N 34 59 W 854 11 5700.00 5473.44 5416.44 30 10 N 35 13 W 904 06 5800.00 5559.79 5502.79 30 9 N 35 28 W 954 37 5900.00 5647.23 5590.23 28 19 N 36 1 W 1002 69 3,51 1 .32 1 ,05 3,50 0.63 0,82 1 ,22 0.18 2,40 0,66 455,61 N 259,25 W 524 21 N 29 38 W 504.51 N 289.95 W 581 552.88 N 321.51 W 639 600.50 N 353.02 W 696 644.38 N 383.32 W 749 687.68 N 413.71 W 802 730,13 N 443,21 W 854 771,07 N 472,05 W 904 812,26 N 501,17 W 954 851,57 N 529,57 W 1002 89 N 29 53 W 56 N 3O 11W 58 N 30 27 W 77 N 30 45 W 53 N 31 2 W 12 N 31 16 W 09 N 31 29 W 43 N 31 4O W 8O N 31 53 W 6000,00 5735,24 5678,24 28 25 N 35 49 W 1050.00 6100,00 5823,13 5766,13 28 32 N 35 21 W 1097.55 6200,00 5910,85 5853,85 28 48 N 34 52 W 1145.43 6300,00 5998,35 5941.35 29 9 N 34 25 W 1193.76 6400,00 6085,53 6028,53 29 33 N 34 7 W 1242.66 6500,00 6172.31 6115.31 29 56 N 33 47 W 1292.28 6600,00 6258.94 6201.94 29 39 N 33 23 W 1342.19 6700,00 6346,57 6289.57 28 20 N 33 7 W 1390.32 6800,00 6434.66 6377,66 27 48 N 32 55 W 1437.61 6900,00 6523,03 6466,03 28 6 N 32 50 W 1484,39 0.24 890.03 N 557.43 W 1050 18 N 32 4 W 0.37 928.81 N 585,20 W 1097 79 N 32 13 W 0.32 968.08 N 612.82 W 1145 74 N 32 20 W 0.42 1007,93 N 640.32 W 1194 13 N 32 26 W 0.70 1048.41 N 667.90 W 1243 08 N 32 30 W 0.42 1089,64 N 695,63 W 1292 76 N 32 33 W 1,97 1131,26 N 723,28 W t342 71 N 32 36 W 0,89 1171,55 N 749,67 W 1390,87 N 32 37 W 0,41 1211,22 N 775,46 W 1438,19 N 32 38 W 0,53 1250,55 N 800,84 W 1485,00 N 32 38 W 7000.00 6611.03 6554.03 28 30 N 32 52 W 1531.86 7100.00 6699.03 6642.03 28 14 N 32 59 W 1579.34 7200.00 6787.15 6730,15 28 20 N 32 58 W 1626.58 7300.00 6874 85 6817.85 29 2 N 30 13 W 1674.62 7400.00 6962 21 6905.21 29 10 N 30 31 W 1723.28 7500.00 7049 56 6992.56 29 6 N 30 52 W 1771.97 7600.00 7136 87 7079.87 29 27 N 31 28 W 1820.72 7700.00 7223 82 7166.82 29 50 N 31 44 W 1870.11 7800.00 7310 72 7253.72 29 24 N 32 32.W 1919.57 7900.00 7397 78 7340.78 29 22 N 31 28 W 1968.76 0 27 1290.45 N 826.60 W 1532.49 N 32 39 W 0 40 1330.35 N B52.38 W 1579.99 N 32 39 W 1 26 1369,96 N 878,19 W 1627,27 N 32 40 W 0 55 1411,00 N 903,14 W 1675,29 N 32 37 W 0 14 1453.00 N 927,72 W 1723,92 N 32 33 W 0 36 1494,90 N 952,54 W 1772,58 N 32 30 W 1 14 1536.60 N 977.77 W 1821.32 N 32 28 W 0 88 1578.67 N 1003.67 W 1870.71 N 32 27 W 0.90 1620.56 N 1029.99 W 1920.18 N 32 26 W 1.53 1662.22 N 1056.15 W 1969.38 N 32 26 W COMPUTATION DATE: 2-JUN-92 PAGE 3 BP EXPLORATION M-31 (34-36-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 22-MAY-1992 KELLY BUSHING ELEVATION: 57.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN ,DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 7484.97 7427.97 29 33 8100.00 7571.84 7514.84 29 49 8200.00 7658.52 7601.52 29 39 8300.00 7745.81 7688.81 29 5 8400.00 7833.13 7776.13 29 6 8500.00 7920.82 7863.82 28 41 8600.00 8008.89 7951.89 28 4 8700.00 8097.01 8040.01 28 17 8800.00 8185.11 8128.11 28 13 8900.00 8273.50 8216.50 27 57 N 32 41 W 2017.73 N 33 50 W 2067.22 N 31 35 W 2117.05 N 29 36 W 2165.82 N 29 48 W 2214.54 N 30 1 W 2262.60 N 30 15 W 2309,96 N 30 34 W 2357.23 N 30 45 W 2404.56 N 31 14 W 2451.3t 0.80 0.87 3.28 0.29 1 .31 1.24 0.51 0.37 0.73 2.34 1703.76 N 1082.10 W 2018 35 N 32 25 W 1745.20 N 1109.23 W 2067 1786.86 N 1136.64 W 2117 1829.06 N 116t 09 W 2166 1871.40 N 1185 23 W 2215 1913.03 N 1209 25 W 2263 1954.04 N 1232 97 W 2310 1994.81 N 1256 88 W 2357 2035.50 N 1281 06 W 2405 2075.72 N 1304 90 W 245i 87 N 32 26 W 74 N 32 28 W 47 N 32 24'W 15 N 32 21W 18 N 32 18 W 51 N 32 15 W 76 N 32 13 W 07 N 32 11W 81 N 32 9 W 9000.00 8362.18 8305.18 26 56 9100.00 8451.53 8394.53 26 16 9200.00 8541.21 8484 2t 25 44 9300.00 8631 28 8574 28 25 41 9400.00 8721 45 8664 45 25 38 9500.00 8811 46 8754 46 26 0 9600.00 8901 24 8844 24 26 13 9700.00 8990 97 8933 97 26 8 9800.00 9080 72 9023 72 26 23 9900.00 9170 24 9113 24 26 27 N 30 51W 2497 53 N 30 3 W 2542 N 28 42 W 2586 N 28 33 W 2630 N 28 20 W 2673 N 28 19 W 2716 N 28 27 W 276O N 28 54 W 2804 N 28 59 W 2848 N 28 56 W 2893 2.45 41 2.29 2154 63 0.20 2192 05 0.64 2231 23 0.23 2269 76 0.3O 2307 75 0.24 2346 86 0.43 2384 93 1.43 2423 44 0,00 2462 2115 48 N 1328 46 W 2498 01 N 32 8 W 32 N 1350 85 N 1372 02 N 1393 05 N 1414 41 N 1434 16 N 1455 89 N 1476 48 N 1498 46 N 1519 97 W 2542 7O W 2587 46 W 263O 02 W 2673 70 W 2717 61W 2761 80 W 2805 16 W 2849 69 W 2893 87 N 32 6 W 06 N 32 3 W 44 N 31 59'W 59 N 31 56 W 08 N 31 52 W O3 N 31 49 W 11 N 31 46 W 16 N 31 43 W 65 N 31 41W 9945.00 9210.53 9153.53 26 27 N 28 56 W 2913.48 0.00 2480.01 N 1529.39 W 2913.67 N 31 40 W COMPUTATION DATE: 2-JUN-g2 PAGE 4 BP EXPLORATION M-31 (34-36-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 22-MAY-1992 KELLY BUSHING ELEVATION: 57.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH ,~,OEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -57.00 0 0 N 0 0 E 0.00 1000.00 1000.00 943.00 0 18 N 16 19 W 1.04 2000.00 1999.83 1942.83 0 37 N 63 24 E 10.40 3000.00 2999.79 2942.79 0 7 S 65 57 E 5.53 4000.00 3993.35 3936.35 13 39 N 35 0 W 84.70 5000.00 4886.48 4829.48 34 34 N 31 49 W 524.06 6000.00 5735.24 567B.24 28 25 N 35 49 W 1050.00 7000.00 6611.03 6554.03 28 30 N 32 52 W 1533.86 8000.00 7484.97 7427.97 29 33 N 32 41 W 2017.73 9000.00 8362.18 8305.18 26 56 N 30 51 W 2497.53 0.,00 0.00 0 66 N 0.92 W 1 1.13 15 95 N 6.36 E 17 0.43 14 77 N 13.84 E 20 3.43 83 14 N 26.09 W 87 3.5! 455 61 N 259.25 W 524 0.24 890 03 N 557,43 W 1050 0.27 1290.45 N 826.60 W 1532 0.80 1703.76 N 1082.10 W 2018 2.45 2115,48 N 1328.46 W 2498 0 O0 N 0.00 E 0 O0 N 0 0 E 13 N 54 39 W 17 N 21 44 E 24 N 43 9 E 14 N 17 26 W 21 N 29 38 W 18 N 32 4 ~ 49 N 32 39 W 35 N 32 25 W O~ N 32 8 ~ 9945.00 9210.53 9153.53 26 27 N 28 56 W 2913.48 0.00 2480.01 N 1529.39 W 2913.67 N 31 40 W BP EXPLORATION M-31 (34-36-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED*VERTI.CAL VERTICAL .DEVIATION AZIMUTH DEPTH OEPTH DEPTH DEG NIN DEG MIN COMPUTATION DATE: 2-JUN-92 PAGE 5 DATE OF SURVEY: 22-MAY-1992 KELLY BUSHING ELEVATION: 57.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORiZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0.00 0.00 -57.00 0 0 N 0 0 E 57.00 57.00 0.00 0 7 S 7 16 E 157.00 157.00 100.00 0 10 N 60 52 W 257.00 257.00 200.00 0 4 N 38 53 E 357.00 357.00 300.00 0 9 S 86 44 W 457.00 457.00 400.00 0 2 N 66 26 E 557.00 557.00 500.00 0 8 S 64 44 W 657.00 657.00 600.00 0 7 N 66 4 W 757.00 757.00 700.00 0 4 S 62 59 W 857.00 857.00 800.00 O 7 N 71 48 ~ N 15 7 W N 0 17 W N 10 7 E N 8 16 E N 7 57 E N 9 43 E N 28 3 E N 37 32 E N 41 0 E N 43 43 E 957.00 957.00 900 O0 0 16 1057.00 1057.00 1000 O0 0 24 1157.01 1157.00 1100 O0 0 47 1257.02 1257.00 1200 O0 0 50 1357.03 1357.00 1300 O0 1 1 1457.05 1457.00 1400 O0 1 11 1557.08 1557.00 1500 O0 1 44 1657.12 1657.00 1600.00 1 13 1757.14 1757.00 1700.00 1 11 1857.16 1857.00 1800.00 0 57 1957.17 1957.00 1900.00 2057.18 2057 O0 2000 O0 O0 2100 O0 O0 2200 O0 O0 2300 O0 O0 240O O0 O0 25OO O0 O0 2600 O0 O0 2700 O0 O0 2800 O0 0 54 N 49 49 E 0 33 N 80 10 E 0 41 N 82 9 E 0 37 N 87 11 E 0 42 S 84 25 E 0 34 S 84 44 E 0 24 S 63 17 E 0 25 S 67 15 E 0 22 S 49 42 E 0 9 S 41 49 E 2157.18 2157 2257.19 2257 2357.19 2357 2457.20 2457 2557.20 2557 2657.21 2657 2757.21 2757 2857.21 2857 2957.21 2957.00 2900.00 0 11 5 28 1 E 3057.21 3057.00 3000.00 0 4 N 68 51 W 3157.21 3157.00 3100.00 0 20 N 33 4 E 3257.21 3257.00 3200.00 0 27 N 17 31 E 3357.22 3357.00 3300.00 0 22 N 19 21 E 3457.22 3457.00 3400.00 0 46 N 15 58 E 3557.38 3557.00 3500.00 5 38 N 28 47 W 3658.26 3657,00 3600.00 8 28 N 33 25 W 3759.40 3757.00 3700.00 8 53 N 33 3 W 3860.78 3857.00 3800.00 10 6 N 31 12 W FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 0.00 0.00 0.48 0.04 0.08 0.55 O. 19 O. 10 0.05 O. 16 0.26 0.41 0.29 0.18 0.31 O. 15 0.33 0,33 0.23 0.33 O.OE O. 17 0.42 O. 16 O. 15 0.54 O.OC 0.2i 0.83 0.19 i.35 0.33 2.16 0.07 3.25 0 O0 4.52 0 18 6.00 0 77 7.59 0 58 8.75 0 21 9.44 0 18 9,99 0 O0 10 34 10 26 9 78 9 31 8 69 8 03 7 49 6 85 6 3O 5 86 0.48 0.30 0.05 0 O0 0 O0 0 06 0 32 0 O0 0 18 0.17 5.65 5.53 5.69 6.07 6.54 7.04 11.73 24.94 40.07 56.72 0.16 0.23 0 86 0 46 0 O0 1 54 5 03 0 O4 0.97 1.06 0.45 N 0.99 N 2 04 N 3 43 N 5 05 N 6 94 N 9 32 N 11 53 N 13 13 N 14 51 N 15 60 N 16 10 N 16 20 N 1633 N 1630 N 16 20 N 16.01 N 15.69 N 15.36 N 15.07 N 14.86 N 14,78 N 14.99 N 15.66 N 16.32 N 17. 10 N 21.63 N 32.78 N 45.44 N 59.53 N 0 O0 E 0 06 E 0 15 E 0 07 E 0 O1 W 0 10 W 0 25 W 0 36 W 0 55 W 0 70 w 0.86 W 0.97 W 0.8O W 0.59 W 0.36 W 0.11 W 0.77 E 2.20 E 3.51 E 4.74 E 5.88 E 6.89 E 7.97 E 9.11 E 10.26 E 11.37 E 12. 10 E 12.81 E 13.35 E 13.72 E 13.76 E 13.86 E 13.90 E 14.27 E 14.46 E 14.79 E 13.21 E 6.12 E 2.17 w 11.06 w 0 O0 N 0 0 E 07 N 57 22 E 24 N 38 40 E 18 N 25 3 E 29 N 2 21W 18 N 34 3 W 34 N 46 44 V~' 40 N 64 49 57 N 74 35 W' 73 N 73 6 W 0 97 N 62 29 ~' 1 39 N 44 31 W 2 19 N 21 29 W 3 48 N 9 48 W 506 N 4 5 W 6 94 N 0 54 W 9.35 N 4 42 E 11.74 N 10 49 E 13.59 N 14 58 E 15.26 N 18 6 E 16.67 N 2O 39 E 17 52 N 23 10 E 18 O6 N 26 11E 18 70 N 29 9 E 19 26 N 32 11 E 19 79 N 35 3 E 20 07 N 37 5 E 20.26 N 39 13 E 20.35 N 40 59 E 20.38 N 42 18 E 20.26 N 42 48 E 20.26 N 43 10 E 20.44 N 42 50 E 21.19 N 42 21 E 21.80 N 41 33 E 22.61 N 40 52 E 25.34 N 31 25 E 33.34 N 10 34 E 45.49 N 2 44 W 60.55 N 10 32 W BP EXPLORATION M-31 (34-36-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 2-JUN-92 PAGE 6 DATE OF SURVEY: 22-MAY-1992 KELLY BUSHING ELEVATION: 57.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH T.RUE SUB-SEA COURSE MEASURED -V~-RT~CAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG ENGINEER: JEFF FORMICA VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTE FEET DEG/IO0 FEET FEET FEET DEG MIN N 33 2O W N 35 21W N 33 45 W N 33 6 W N 33 52 W N 32 51W N 29 46 W N 3O 37 W N 30 42 W ,44t N 31 30 V~' 504 3962.69 3957.00 3900.00 12 23 4065.82 4057.00 4000.00 15 53 4170.89 4157.00 4100.00 20 7 4278.79 4257.00 4200.00 23 29 4388.80 4357.00 4300.00 25 39 4500.61 4457.00 4400.00 27 30 4614,40 4557,00 4500,00 29 30 4729.94 4657.00 4600.00 30 27 4846.41 4757.00 4700.0C 31 18 4964.48 4857.00 4800.00 33 22 76 32 101 38 133 46 173 92 219 70 269 65 323 92 381 7E 24 5086.37 4957.00 4900.00 35 21 N 32 34 W 573.92 5208.89 5057.00 5000.00 35 30 N 33 14 W 644.66 5329.98 5157.00 5100 O0 32 31 N 34 27 W 712.82 5447.72 5257.00 5200 O0 31 57 N 35 5 W 774.83 5565.37 5357.00 5300 O0 30 40 N 34 41 W 836.65 5680.99 5457,00 5400 O0 30 7 N 35 14 W 894.54 5796.77 5557.00 5500 O0 30 10 N 35 27 W 952.74 5911.10 5657,00 5600 O0 28 17 N 36 0 W 1007.93 6024.75 5757.00 5700 O0 28 28 N 35 45 W 1061.75 6138.58 5857,00 5800 O0 28 40 N 35 12 W 1115.96 N 34 36 W 1170.82 N 34 14 W 1226.57 N 33 50 W 1283.48 N 33 24 W 1341.09 N 33 6 W 1395.96 N 32 51 W 1449.39 N 32 52 W 1502.61 N 32 51 W 1556.73 N 33 13 W 1610.39 6252.69 5957.00 5900.00 28 57 6367.23 6057.00 6000.00 29 23 6482.33 6157.00 6100.00 29 54 6597.77 6257.00 6200.00 29 42 6711.86 6357.00 6300.00 28 25 6825.26 6457.00 6400.00 27 48 6938.55 6557.00 6500.00 28 20 7052.27 6657.00 6600.00 28 21 7165.77 6757.00 6700.00 28 10 7279.59 6857.00 6800.00 28 56 N 30 t6 W 1664.72 7394.03 6957.00 6900 00 29 10 N 30 30 W 1720.37 O0 29 5 N 30 56 W 1776.11 O0 29 31 N 31 33 W 1832.11 O0 29 49 N 32 2 W 1889.13 O0 29 34 N 32 14 W 1945.71 O0 29 19 N 32 16 W 2001.96 O0 29 45 N 33 38 W 2058.73 O0 29 40 N 31 39 W 2116.19 O0 29 7 N 29 37 W 2172.05 O0 28 46 N 29 55 W 2227.71 7508.52 7057.00 7000 7623.13 7157.00 7100 7738.25 7257.00 7200 7853.15 7357.00 7300 7967.89 7457.00 7400 8082.90 7557.00 7500 8198.26 7657.00 7600 8312.81 7757.00 7700 8427.26 7857.00 7800 3.67 3.76 5.70 2.53 1 .88 2.15 1.14 0 0.97 3 76.19 N 21.37 W 79.13 N 15 40 W 96.78 N 35.77 W 103.18 N 20 17 W 123.28 N 53.96 W 134.57 N 23 38 W 157.20 N 76.06 W 174.63 N 25 49 W 195.39 N 101.38 W 220.13 N 27 25 W 237.04 N 129.05 W 269.89 N 28 34 W 283.51 N 157.08 W 324.12 N 28 59 W 333.56 N 186.12 W 381.97 N 29 10 W 384.89 ~ 216.63 W 441.67 N 29 22 W 438.74 ~ 248.85 ~ 504.40 N 29 34 W 2.10 1.14 3.53 0.73 3.26 0.08 2.25 0.48 0.24 0.49 497.89 N 285 69 W 574.03 N 29 51 W 557.19 N 324 613.98 N 362 664.94 N 397 715.76 N 433 763.27 N 466 810.93 N 500 855.83 N 532 899.59 N 564 943.89 N 595 34 W 644.72 N 30 12 W 19 W 712.85 N 30 32 W 77 W 774.83 N 30 53 W 22 W 836.66 N 31 11 W 55 W 894.56 N 31 26 W 23 W 952.81 N 3t 40 W 67 W 1008.06 N 31 54 W 32 W 1061.94 N 32 6 W 87 W 1116.23 N 32 16 W 0 53 0 41 0 23 1 89 0 65 0 39 0 74 0.19 0.24 0.90 988.99 N 627 31 W 1171 16 N 32 23 W 1035.08 N 658 1082 32 N 69O 1130 34 N 722 1176 28 N 752 1221 12 N 781 1265 86 N 810 1311 35 N 840 1356.38 N 869 1402.45 N 898 85 W 1226 73 W 1283 67 W 1341 75 W 1396 86 W 1449 72 W 1503 09 W 1557 34 W 1611 16 W 1665 98 N 32 29 W 95 N 32 33 W 61 N 32 36 W 52 N 32 37 W 98 N 32 38 W 22 N 32 38 W 37 N 32 39 W 06 N 32 39 W 40 N 32 38 W 0 18 0 36 0 7O 1 39 0 ,85 1 16 0 77 331 0 27 1 37 1450.50 N 926.25 W 1721.01 N 32 34 W 1498.45 N 954.67 W 1776.72 N 32 30 W 1546.31 N 983.73 W 1832.70 N 32 28 W 1594.83 N 1013.71 W 1889.73 N 32 26 W 1642.63 N 1044.01 W 1946.33 N 32 26 W 1690.45 N 1073.63 W 2002.57 N 32 25 W 1738.12 N 1104.52 W 2059,38 N 32 26 W 1786.12 N 1136.19 W 2116.88 N 32 28 W 1834,48 N 1164.17 W 2172.70 N 32 24 W 1882.83 N 1191.79 W 2228.32 N 32 20 W COMPUTATION DATE: 2-JUN-92 PAGE 7 BP EXPLORATION M-31 (34-36-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 22-MAY-1992 KELLY BUSHING ELEVATION: 57.00 FT ENGINEER= JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH · RUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTPi FEET DEG/IO0 FEET FEET FEET DEG MIN 8541.17 7957.00 7900.00 28 17 8654.57 8057.00 8000.00 28 14 8768.10 8157.00 8100.00 28 14 8881.35 8257.00 8200.00 27 37 8994.19 8357.00 8300.00 26 55 9106.10 8457.00 8400.00 26 21 9217.52 B557.00 8500.00 25 43 9328.53 8657.00 8600.00 25 35 9439.46 8757.00 8700.00 25 48 9550.70 8857.00 8800.00 26 8 N 29 55 W 2282.25 N 30 24 W 2335.71 N 30 51 W 2389.47 N 31 0 W 2442.62 N 30 48 W 2494.90 N 30 8 W 2545.12 N 28 37 W 2594.23 N 28 29 W 2642.38 N 28 20 W 2690.32 N 28 20 W 2739.03 1 .85 0.38 0.35 2.27 2.41 2,35 0.33 0.37 0.6~ 0.18 1930.06 N 1219 06 W 2282.81 N 32 17 W 1976.27 N 1245 96 W 2336.25 N 32 14 W 2022.54 N 1273 34 W 2389.99 N 32 12 W 2068.28 N 1300 41 W 2443.12 N 32 10 W 2113.22 N 1327 11 W 2495.38 N 32 8 W 2156.66 N 1352 32 W 2545.58 N 32 5 W 2199,53 N 1376.35 W 2594.66 N 32 2 W 2241.87 N 1399.36 W 2642.76 N 31 58 W 2284.12 N 1422.14 W 2690.67 N 31 54 W 2327.03 N 1445.27 W 2739.32 N 37 51 W 9662.15 8957.00 8900.00 26 12 9773.53 9057.00 9000.00 26 20 9885.21 9157.00 9100.00 26 27 9945.00 9210.53 9153.53 26 27 N 28 46 W 2788.16 N 29 0 W 2837.19 N 28 56 W 2886.86 N 28 56 W 2913.48 0.19 0.87 0.00 0.00 2370.27 N 1468.75 W 2788.44 N 31 47 W 2413.20 N 1492.46 W 2837.43 N 31 44 W 2456.70 N 1516.51 W 2887.07 N 31 41 W 2480.01 N 1529.39 W 2913.67 N 31 40 W DIRECTIONAL SURVEY COMPANY fiELD WILL COUNTRY RUN DA11 LOQQIO DEPTH UNIT BP EXPLORATION PRUDHOE BAY M-31 US& ONE 2~ - IWt&¥ WELL' M-31 (34-36-12-12) ( 2082' SNL,606' WEL,SEC 1,T11N,R12E) HORIZONTAL PROJECTION RECEIVED JUL - ~ ~oo ~'~.& Gas Cons, ~,u~misston -.. ~o~Jorag~ ~'JELL' H-31 (34-36-12-12) (2082'SNL,606'[':EL,SEC !,TllN,R12E) VERTICAL PROJECTION 5OO 10(~0 1500 20(X) 25OO 3OOO ' iii .-!-.~-.4-4 ..... i-4--~-.-~ ...... ~--4...~---L.J---L.-i--L-.! ....... i..]...':..~....~...i...:...i ...... !..!-.L..i...L..~...i...i...i ..... i...i..i...i ..... L..~...~..~ .... i.i.~ ~ '~ F'i f ! ~ ~"'~"~'"~ ~"'~"'i"';" ...}-+-:---:---,-+-+-+--,~..--:.--.'....:-..i ...... ~..-.1-~.--~...;-4...i-~-.J....j...~...'.4. ...... !--i.--i--.i ...... ~...~.:;...! ...... ~...:.--i-:- - i.~ .~...i ..... :'..~..i .............. ~ .~ · . · r'!"'r'~ ...... r'r"r'-~ ...... !"~--'!-"i'--!'+-'--H-"!4 ...... i+-H'-..!'...i.+-i ...... ~...i.-.i-..! ...~-.~...i...i ...... ~...~._L..~ ,, ~, ':: :: · ..... ..... ....... ...... L.H...i ....... i4..-i...i..,'...i4.+.! .... i...i...:...i ...... ...... i ...... ...... ...... ....... ;...;..i...' .... ...... ...... ..... ...... ...... .... ...... ............... i ...... i ....... L.i ...... i ..... "T"FT'i ...... ;"~'"F'i ..... P'!"'!"'! ..... h'!'"P'i ...... i"i"?~ ....... hi"i"'~' ..... ~--.~-..i.-.~ ...... '"'~"'i'"' ...... i-.~-.-!...~-. ~-..!..-~...~-.~ .... i ......... ~ ............ ~ ......... ~ ...... ~ .......... }...i-.'.4 .... : : ~ :~ : : : .. [ ~)~q"lt'l~ : : : ..... ~ ....... : : : --~--.:-.-.--~-....-t.-.:--:--.--- -.: ................. .-.-. ........... :.....-..: ......... ..-..: ........... .'--4.--.1---i ...... ;~'.' ............... F ............ .1 ..... .1 ........ i ..................... :..4 ................ 4 --. ~..: - ~ : - · · '!"i-'~"-,:"t'-P-i-'i-"i ..... i"-f ......... t~-i-"f--i"i ...... !'-'i-'i'-'~ ...... !-.i..i.-.+-~ '--!--'i--i--} ...... i"'!-'-! ......... i'-i--~ ......... ~ ..... .:.-4 ..... ~.4.4...i ...... i.-i...i...i ...... i...i.4...i ...... ~.,.i..4...i ...... --,+'i-'i-'i .... i--k'-.~i ..... i'-'.~--P'i'--,--i-'-.:''-.:''i'-'~'--f-'-i-'i''-i ..... i"i"i"i--'l-..~-'-!--'r-i ..... i'-i--i--i ...... i'"i'"i"i ....... i'-i'-~-..i..~!:.i...i.-.i.,,i ..... 6.i...i..4 ...... i...i.-i..-~ ..... i..-i...i...i... ]iZ!':~"i ..... ht--i'--i ..... H"i"i ...... i-i"!'"~ ..... i"!"i-! ...... !"i"'?"!''~t'~!-!-!'"! ..... i"'i"i"! ...... ?"hl-'! ...... ?"!'?i'"i-'i'"!"'!"'! ...... i'"f"!"'} ..... i'+i"'i ..... i'"i"'i'"i ...... · .+-.:-..!..-:' ..... i ...... .1...i..~ .i..-i...i-.i ............ .; ............. ~ .................. i ...... .1--.i..+.-~ ........... i ...... ,-.i...i ...... i ...... i...': ...... i ...... i...:' ..... .~ .~...~ ...... ~...!...~ .... :_ ~ i i. ,f'~-'~:-~ ..... !'"m'r'~ :~~'"i'"r": ........ r"f"! ...... !'"!'"r'"'":"~'"r"~'-~ ...... i-:"'!"'! ...... !'"!'"i'"! ...... f"!'-i-P-'i'"i-"!"'r[ ...... i'"i"~ ...... i'"~-':'"i-''~''i'''i'-i ...... ~'":"!'": ...... ]:." L...1::~:]: ::i:::i::i~ :::i::~ z ~::!:: i:: i: i 2 i: ! ] !::i::i i :i i::i: i:: :: i: i:::i:::i]:i:::i:::i:::i:::!::::::i::t::?i'---"t'i--i-"i'";'"i'"i ...... i ..... i.,.! ........ :"i-'*i'"f.i ...... i--i..-i.-i ..... f"H ...... 4"!"!"!':'-!4'-'! ...... 4---!'--?'-.-+-!"i'-! ..... !"i'"!'"!"'i"!'"H'"i ...... !+!...i ..... i.-.H...i ...... !4 ...... i ..... H...!+-..-! ...... ...... -.4-4..4-4 ..... i..-i--.6-6:..-:..-i...:-..~-.-..i ......... i ...... .~.---~:.i ......... i ...... i---6.i-4 ...... i ...... ': ........ L..L.~ ........ L.L_i .i .... i !.. i .; i ] i ..i : : : : : ~ , : : ~ : : i : : : ~ . · : : ~ ~ · : · : : : · ; : : : : : : ~ : : : : : : : : : -~"i"~"~'" r?"r"? "',' ...... .:'".- ........... r",:'" ~"',: ......... ..'"' '~'i'" "".'";'--":'", ......... ~ .............. .:.-.1.., .-i..+..i ........ ~ .................... ~ ......... ~.-.1..+..i-.! ..... h.+,.,: ............... i .................. · ...... H--.!---i--.i...i ...... !.--!,.-4 ......... ..-H-.VE ,--i..-?.!:.-i:'.-.!....-:):::i:::':::i:::i::i:::i::: ii i ~ ! !;i' ~ i ! i i"i ! ~ i : : ~ i i ! ~ ~ ! ! !.."'-Lj i ~ : ! : ~ : ,. : .... ~ i i , : .':', '~ ,, ; : ! ; ; f i "i"T'!'":'" F'?':'": _~.. '".'"':-':"': ...... ~'":'":'".'"~ r'-:'-':-'-.'---: ...... :'":--':-": ...... :...:...:...... r.- :-~-:....:. ..... :--.~-.h-..:..~ .-h..i--h-..1 ..... F...1.-.h...1 ............. -;.-~-i---h.4 ....... .1 ......... ~ ..................... · .?..-.'-.: ..... 6..:...4~ ...i..4...i...~ ...... i.4...i...~..,i...~-.~.4-.i ...... ~..4...~...~ ......... ~...i.4 ...... ~ ,..i...!~64...~,4...i.4-~ ..... i,..i...i.4 ...... ~..!...~...i..,;.4...i...6.i- -:'...i...i.4 ...... i...~...~...~ ...... · ..i.q..~..4..,?...i-~...!...6.i...~ ...... 6.i ...... i ...... i ...... i...i ..... ~ ............... i ........ i ...... i ...... i ......... ~.~.i ..... i ..... 6.:. ..... i...~ ...... i ...... L..L..L..i ...... !..4 ............ i...i ...... ~ ......... i ...... i..I..i...i...L_i._ :::!::i:::i::Y:: :::i:::i:::i:::i:::':::i:::i:::i:::i:: :::i:::i:::i:::i::: l:::!:::?!:::i:: ::Y:t:i::?: · ?-~-~..4.....-:'..4.q.mm ..~..~-:'..4..~...i..-:'.4...~ ...... i...i...6.~ .... i--.i...6.i..-..-.".--.1...i.-i.....4...i...i-.i...64...i.4...6 ,..i-.i.-i..4.. -.]~.."~+...:..~..~4-.i..~.., .-:'.-i,..i...6, -,-!..+..,:.., ,.~...i..~...i .... i-.i..4.4- ,.4,.+.4..4....4-i-.~ .-!-_-~W:.6q.-4.-4-..i ......... i-..i..-!-..i ..... i...i...6.6~..4.4..4-! ...... i..4..-i.,.i.....-i..4,..i...i ..... ':-..~-~-:. .'~.-..~4-"-".~-;. · "-".--.:-.':- ,.L.~...; ~. .~-~ ..... ~--i '--!d--i-q ..... i--i-'-:,--i ..... i---i'--!'--! ..... i'-i"-::'-'i ...... k'i-'i--'i ...... i"'i-'-i--i--q'-i-"!'-i'-'i ..... i-'-::'--i-'i ...... i"i"i-'i--'~'--!'.i.fi-,-! ...... 6.i-..!...i ..... ~'"{'~ ...... i"-i"i'"i ...... i-'+.i ....... i~'i".i"'i'-, '"Pi"i"i ...... f'"h-P'i ......... f"'P'f'"l'-i ...... ! ......... i"i'"!"'f'''~ .................... f"i ........ k"i ............ F"!'"f'"i ...... ,;"-!"+-'~ ..... 6..1...6.~ ..... ~4.'-~ ~ ..... ~..+--.1..+-!....~-..6-.:..+-~..+.+.,i "i--i"i---:. ...... i--'~."i'4--,'--!'--!-'i-.'! ...... ,i-'i'--! ...... i-"!'-i"-,i ...... ~ ...... ! ........ ~"-!"-~'-'! ...... ~'..!'--~..'~ ...... !...~,--~..-~ ...... ~....1.o!...~--.i--.~,4-.-~.-.~ ..... ~...i...~.4...~...~..i ..... i---i.'.F-~ ...... '--!-"i-'-.:'--.': ..... h'!-'i~i ...... i'-'!'-+-'~ ..... .~ ...... ~ ......... ~-"~-'-~ .......... ~-"~---i'--~ ..... !"-.:'-'~--i ......... ~--i ......... ~'--.~"..' ......... i"-!.-! ................ i"'! ......... i"-! ......... ½"'~;2 ...... ~ ........ i-"! ............ i'"~ ,-4---i.--i..-i ..... i-..i-.-i.-.i...i--.i....~.-.i...i ..... i...~....;-...i ...... i...i...6.i ...... ;...6-i...i ..... i...6.i...i ...... ~...i...i...i ...... ~...i...i ......... i ..... i...i ......... ~...i...i ...... ~..i..4..4 ........... i ........ 4..~...~t44s-." ~.. ~ ~ ~ ... : ; : : ~ ~ : : ~ : ~ : : ; : : ~ : ~ . : ~ : ; : ~ . . .... : · ~ .... ~ . "'}' '~"'.'":: : ~ ...... i'"~'":"';: : : .... ~'~."":-'.-':'-': : : '":-":"'r'-:: : : : .... :~"';'"r":: : ; ...... :;'":'"r":"~ : : ..'t..'t....:.-:: ~ : : ...... :;'""":'";::: ...... :;'"r"~: : .........: .....:.-:-.:.. ...J. ..... .""~"':"'"'". ..--...t-....,~.~ ...... }.-:....!..4L : : ...... !~ ...............: TT'T'T"'TTt!-F''["'i-'i'"~''~ ..... F'T'T'T~''i''T'T''i ..... F'T'TT' "i-i"T'!''~'''i-:."'T''~ ...... ~"T'T"! ...... ~'q'~. :-:-'!'"r"!'"~ ...... ~-'r-:r-'; ..... r-: 'T'T""?'r'T"r""?'""i'": ..... ?":""..'-,;::;: ...... : : : i I*~l, .,r'°!'''r''..' ..... :"~' ?°'.1'"..'"'.::::: , ~ ;. '. :r"r?'"' ...... : : : :r?"r'": ..... : : : : , : : t !r'":'":"""' ...... r"r"r"~ ......... i : i ;z'"z ......... ~ : , ;i'"r-~"'i'""'i"'i'-i"'! I 1 ~ t i : e i : ........................... '. '. : ~:' ............ : : : :i ............ "~-i"t'i.'. ..... i'q'"[-!'" ½~-i-.:-.-.~-..-+--.:--;-.-.:.:..i.-.~--.~...~ ...... ~-~..-~--.~-....i.--..'.--~..-~..~.-.~-~.4.-~ .... [--...:-,..F-.--H-F-F--,'-+~--; -.-H. ~ ?" ..... i--i...F.~-.-+-.i..+.~ .... ~.. H...: -.4 .r.: 4-. ,-'r-"..--.,-,; ..... ,'-,,i-,,'.'-,,,: ...... !-.,i--i,,-F, ,,4,,,,'--,-,',-,.', ...... P-,.1,.-i--4 ...... i-4---i-'-.; ..... i,,-.'-,4--.1,,- --4-4---i--4 ...... !,,,.u,,F,4 ...... F--i--.'-,i ..... i,,,i---,:,,,i,-, I,,-F,,i-,,'.-.,,.1 ...... F-.~,-,i-,,~ ...... F,.F-4,,4 ...... i,,,i,.-.'-,,i ..... F-,F.4-,,F.- ..................................... --:...;."---;.. -4...;..~.:....:.. :...,...: ...... ~."-...;..., ..... :"'~'":'"i ...... ~'"~"~'": ..... ! .... i...L.. · ':'--."-~o'-., ~ . : ...... -~ ~:"':--:"'::: ...... ~:""-'"'"t'",: ~ ,-~-.-:-.-.-.:: .......... ... ~ :'-';--:---;:;: ...... :"-.'-'-:'~'";,:: "~-"t.'-:-~.*: , ~ ~ ..... ::'"r"""?~:: --'..-':-.-.-..:.--s: ~ : : : : : · : i ' : : : : : ; : : ~ ~ : : : ~ : ~ : : "':-r'??-' :"'r"..'-..'"' .,-~,-.,"-r" '?":'"'r".."'~"'!"':'-..-~ ..... m:'"'r'?-?-..-r~.-,--,,--r-r-?'-?~~'-..'-'-k"f--i-P'-~!--Pi ....... r"}'".:-"! ........ !'".~'-i'""+'i"i'"~ ...... i"'f"~'"! ........ !'"!"i"' : , ; : ; ': ; :: r', ', ': i ; ; ~ ;' ; ': ~ ; ': ': ~ ; ': ; ;; ; ~ ; ; ', ': ; : ',,~ i ' : i : i i ~ : : '. i i '.. ~.i.: : ', ; : : I i : ' ..;.~..~..4.....:......~-.,... ,..~...,...:_.: ...... ;..~...~.., ..... :...:...:...; ...... :---~.-~..' .. ,-+-.'.-.'--~ .... k-~+.-,;--- --+-+-..:..-: ...... L..;.A_~ ...... L..':...:-..-: ....... :L..i...~..4 ..... ~.-~...~...i ...... i...i.--i...! ...... : i i : ,'" i ~ ~ : : : : : : : : : : : : ' : ' : · ' ....... .-u. .... _...~ ..... -~--~--~--~--~-~-- -'-.-'-~-,.-4 .......... i--~M--~ .-4--4-4-~- -4-~.4-4--~..4-,'-.';--.i-~..--~4.-!..4 .... 64.4..-6..-.64...i...i ...... i.-i.--i...i ...... 6.i..4-..i ...... i.-4..4-..i ..... i-..i...i..-i.-- .--t...-t--~- .--t--~ · .-t.--?-- ..~.o;-.. ~..-:...-t--?-?....:_~..~. -: ..... :...:-.;...: ..... ;..-;--?- .-t... - ..t--t.- .-~- --:-.t"'-r'..~.--~ ..'~---r'.':"-; ..... r":--;'-'t ..... ."* .'~-~"'; ...... ~-.- ...:...; ...... r-.;.'.r..t ...... .-"t-.":-"~ ...... :.";'"~-"~ ..... ;..-r..;-..t.-- ..-:-..-L.~.~.4.4--L.-:-..~..~..L..L.-L..L., _L..L..L.4....2...i_L..:.... ~ ~ .. ~ T'! , : ~ : : : ' .i : : : : : '. '. : : : : ~ : : : '. ~ : : : ' : ~ : : : : , : : : ~ i ! i ~ ~ .: ~ ! '-' "~' .'~' : ~ : : '~..' '~.. ! .1 ; : , : ; : :~::q-'* ...--..---t---t ..... :.-:'-;-'-t .................... ..... t---~....-.-. ............. :...t ...... :.-: ...... : ...... t...~...: ............. i ;"~"": ....... ..... t..'~'-.;-.';-.. ~ , ~ ........ ~ ..... ~ . . ~ : i , il ; ,-.' ', f ' ' ! ' · ' L~ .............. t · ' .... i ................ ' : : .... : : ' ' ..4.....4..4..~ ~..~...~."- ........ ':' '-- ' "4'":'":"':" ...:..4--~..; ..... :...:..:.-~--..3--.~--..~...~...~..~--.~.' ...:...:..4 ........ :..,..:-.4 ..... ;"""': '~ .... ~" '"';"4'" [ ;'':" :'"; ' '"~ .......... : ..... "':'"i"'.'--.'"'] --i--!--4--';"' --4"':" .~".:''' "4"4'":"4'* "4'"~-'.1"4 ...... !--'!"';'".:'" '4"4"4.'""i: ..... .:" .'~4'"."" ''4"+'4'".1"~ "4'".1'-P"F;' "'.U'°k'4"'.U" '"i'".:'"F".:"' ~"4'-F"h"F"l "'.:'"!"'!"4 ...... F"F"P".1 ...... F'-F"F'4'" : : ; : : : : : : : : t ; : : : : : : : : : ~ .' ~: , ; ; : : : : : : : : : : : : : : : ~ : : : : . : : : : . t ; : : : : t : : : : : ...-...t.-.-~.-?....; .-.--t.....--t: . : . .... ~-;-..-.-:--..: . ..~'---.-~.--~-*:.: ......... .-?.--t.--t--..---- .-*-.-.-.-- .--~-. , .~-~-?-t.-~.. --t-~-..t-?-:....--:--~.-~.-.-:... ......................... ...t.--r-;--.'-.---~-.:.-.:-.: ...... .--:.-.:--.: ............ :...: ...... ?-.t ...... : ...... ~...:..-....: 4 .1--4 ·t --'-- ~. . · .............. ~.. ......................... ~ ' 4 ' :", :". , r m, -' - :~?'r'-r' r??":"? -r:--mt ..... .'."-r-.7- .?' "'..'"~-'r. ' -t' ..--'r-? "?f'r"r! '-.."-r-.:'"~ ...... ~'r'r"., ...... r'.'.'":'"! ...... r-.'.-'-~ ........ :.......-.:-..:-.,.I "-t" :"i'"? ..... f'"i-'i-"i" i ~ : : : ; : i--: : i : , ~ : i : : : :,: ,: : : : : : : ~ : : : : ~ : : : i : : : : i : : : i :,i ~ : ; , : : i .-' : i : : : : : : : ~ . : · ; : ~ : : . : ......... . . . ; : . : : : , ; ~ : ; : : : : : ~ : : : : : : : : : .. : : : ~ : : : .. ~ , ' ' ' : ;" : :-..:-.-i ..... 6' ' "i"?i-,." 'n-r"m'"'"":"i"~'i'"~'~'i--'i'-'f'- "i-'i'"r"r':-':'"'..'"'r'?"-?"~: . . -r'r".,' .... :""r":'"':'"i'"r'r-m ...... r"r".,""~ ...... r"r"r"; .......... m'"~ ...... :""r'm, ..... .""T"r'i ..... ..'"'r':'"'F' "'i"~-i'~'- '.,~,,'-~!"~-fi;.4"'~+" .--?~q..'- -:'-~-~'".1-~-":"ff-9~-'-'~'!"~--:'-i"~'.:-'-.:'" "!'"~"!'"!"t'"i'"f'-i'-i ..... ~'i'"f"'i ...... ~-.i...!...f ...... i'-i-'!'"i'" "i'"i"'i'"i ...... !'",.'"';'"~ .... !..-!'"i-.-r ......... : . ~ ; . . : : : : : . ~ ........................................... ~--.-..-t..~--t .... ;--.*..-t--?-~ --t--?..?-..---. -~?.*.-..?o?- .--.---..--.-..--; ..... .--.-~-?-?.. -..t..--~. --;--t-- ~---?..1--.-.-t ...... ...-~---:.-.t ..... :.-.:.-...-.: .... ;-..:-.;.-.; ..... .'-..t...;-..t ...... ;.-;-.-r..t.-. [...?...:...~...t ..... ;..-;..?-.~ .... ."-..;'..; ...... : ~ : '..4' : .... : .... ..:. ! ...... : ' ' ; ' ' ° L: : : : : : : : : : : : : : : : : ; : : ; : : : : : : : : · '?~.'"~ ....... ½"~--!- -~.' ...... :--:-'. *'~'-. · .~"* .-~. -~.'-*-.:.'4.--! .... .i-.t-.-!--'.'-" ...:....'....I."-.. ~_..;...~..~.......~.....~..:...: ..... t.."t.-.--'-: .... ?..:'--?'; ..... .~--;..-;--.: ...... : ..... ~ .......... :o"; ...... : ........ .-.-.:..-t ....... :-..;...;...:'.. : : : : ~. ~ : ; ;tAtV~iI~ : : : : · : : : : :, i : : : : : : ~ : : : : : I : : : : : : : : : : : : : : : : ; : · · ; .... : ..... ~" , : . I : . ~ ~ I z ~. , I . I .... J .... ! ! , I , I ..... '~ , , , , , ; I .... I .... -..6+-4.-4'.- -4.'-~.. -4-.;--.."-..~--~..~.4..4.-+4-i-6 -4 ..4-..~..:--.-.'.-4--4"-6.-4--~4~."....-i-~-.4.-i ..... i~.i.-i-.i.....4..4.-.6.:-......':..i...i...~ ...... i.~i..-64 ...... J--i..4...6.,-.i...i..4-i ...... i...i...i...6. : : : : : : : : : : ,~ : .: : , : : , : : : : : : ~ : : : : : : ~ : ~ ~ : : : : ; ; : : : ; : : : : : : : ; : : : : : : : : ; ; : ; -.-.'.--~-.':--':-..'~.:..-t--;...-.~ .?~?..--- -~~. -?..~-..t.- ,---.--.-~;--~. .... t--.:.--.--?.- --.:--lo--t--.--. '-~--t'.'."-':'" I-'-t"-.~--:'--t .... ;---:"?"-; ..... t--~.-.;-.t~..--;...:..?.-: ...... r--t...:...:......~-.-:...r.-~ ....... ~...t..-:...; ....... ~..-:...~...;... -4-.~.4-4.- -4-'-'.~-~ =:--4~-~.~...4.:~:.~.. ~.~ -~-±-£~.--4.-~4- :-- .... :-±.-:...,~.-:-.~.~--! .... i-..~..-~-.¥ --:--.~.-.i-~. ,.4-,.} ...... 4 ...... :-._;....i...~..,~.~,....:...:....! ...... ~,.~...i ..... .1...~-+.,i... .... : ; ~ : : : , · : , : · : ; , : : . · : · : : : : : /: : : ; · : t : : : : ~ .: : ; : : : : : : ~ : : : : : : ' · .4..4..'t..4....~...4...)--;.- --t.-~..i...i....-4..~---i-4 ..... .:--4--i-4 .... ~ .-~.' .~--..~.~-~.'4---4-..4--+--.`-. !--.i..-F.-P--~ ..... ~- .'-F-k-.: ...... !....;--.:-.: ...... .-.4-.'.'..-. ....... .;.-F..i-.4 ...... .~...F..F..i ...... '...i..4...: ...... :....1-":....;--- : ' ' '; ' ; : ~ ; ": :" "" : i i.~ i i "i' i : : : : : : : : : : : ' : : : : : : : : : : :. ' :. ~ ~ ~ ~: : : ~ ' ~ : : : : ~ : : : : : :j_: : · : : : :!!: :::ii!i!! ! ~ i : :!~! ~ii: : : : i · ' : : : : : : · '.. · .~....~.4.'4.. ~... · -~-:.-...~--~--;.'4-- .~~--t.--.--~-.. ~.+--~-..1..-t--..--.--:.-.---; ..... : ...... t-.: ...... .--.:--.- ..... --t ........................ : ........... ~ ............. ...~.~4...~...:..~.?~ i ~ i ~' ~-,,'~,~",'----~,~-~--.'-.,-.;..-.'-'.:--'t'--".-'~'.--.--t---?'.'~-'.""t ....... :'"r'~'":- ?'":'": ...... ; ...... .'"-:'":"'t ..... r";'"; ........ ;--.' .................................... : ..... ~ ...... .'"-r-- ~ : : :: . ; : . : ~_; : : : : i ~ : : : : : : : : : : : ; : : t : : : : : : : ~ : : : "T~"T"-T" ~? ::T: i- ~:::i:: ::;r:??T' --:'"?-~-'r" 'T",.'"':~'T'I" ."',.'?'; ..... ;"?T"! ...... :'"T":"'"! ....... :"'"i-;"'; ..... ~'"!'".v'T" "T"?'T"? ...... !"?T"; ..... ;'"~"'!'":' ...... ;"T":'"'.,' ..... :"",~'"~"'F" "T'T' ~'~.. :: ....... Ii :.'~:::::~-: ..4~._ --~--'- :1~t~, !. ~ ~L-~::-L:~;--L--:--"u'4'"!--':'" ~ : : : -4-..i--..:--4..-:::: -.~o-4.'o-.:o-i-~: ~ : -4.'~4-.oF..i.o.i ~ "- i '-.i--.:-..P..½-.: ~ : : '"'.1"*.1".1'"':'":::: "~' '4"4"'i ~ : i ..... .1'".1'4'°'P"i: '. : ..-.:.-i-.F.-i...:: :, i '·'i'"'.1'"°i"'i: i : : ...... RECEIVED J U L - 9 ~lasI~a .O. jt & Gas Cons. ComrWsSion Rnchqra . BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/06/92 T% 83563 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. M-31 CoM~PLETION / 05/27/92 %1 8992.00- 9595.00 SCH Y-01_,,~ TDT-P BORAX'/ 05/28/92 %1 11750,00-12744.00 SCH Information Control Well Records Adrian J. Martin EIVED JUN 11 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/06/92 T# 83538 BP CASED HOLE FINAL Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. PERF 05/24/92 ~#~-1 8995 . 00- 9670 . 00 SCH l! Information Control Well Records Adrian J. Martin BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 /3 DATE: 05/27/92 T# 83529 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. D-O~ ?r'>? cc~, D-18~1-l~8 PFC .~ ~ ~Z--~ CCL/PERF ~' F-31~'/~'~ TDT-P BORAX / F-45~/--~ PROD-F ~ G-02 ~-~ TDT-P BORAX ~ H-13 ~/'/~PROD-F / 05/10/92 M-26A~-~ CNA / 05/20/92 M-31~Z'~~ CCL/ 05/22/92 ~-~s~.-/~ ~As ~IFT SU~V~ ~ 0S/0~/9~ ~-~-,~.,~s L~FT SU~W~ 0~/~/~ W-3~""'"" f~ FCCL/PERF ~ 05/14/92 x-0~ ~-~ Pm~F ~ Z-19 ~--%3 PERF/'~ r'~ GAS ~NT~Y SUeV~Y -08 ~ USI CEMENT 04/29/92 #1 05/23/92 #1 05/25/92 #1 05/09/92 #1 05/05/92 #1 04/10/92 #1 #1 #1 #1 #1 #1 05/21/92 #1 05/15/92 #2 11500 00-12372.00 CAMCO 5 " 10900 00-11150.00 ATLAS 5 " 10080 00-10369.00 ATLAS 5 " 8750 00- 9482.00 SCH 5 " 9000 00- 9330.00 CAMCO 5 " 9500 00-10231.00 SCH 5 " 9250.00- 9500.00 CAMCO 5 " 9100.00-11770.00 SCH 2/5" 8800.00- 9861.00 SCH 5 " 2100.00-11900.00 CAMCO 2/5" 365.00-10200.00 CAMCO 2/5" 11300.00-11820.00 ATLAS 5 " 9690.00- 9881.00 SCH 5 " 13450.00-14350.00 SCH 5 " 04/29/92 #1 12100.00-12372.00 CAMCO 05/09/92 #1 100.00- 8900.00 SCH 05/09/92 #1 100.00- 8900.00 SCH Information Control Well Records Adrian J. Martin / CEIVED JUN ]] 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 05/26/92 T% 83525 BP MAGNETIC LIS TAPE Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) 564-4004. ~-31 OH/BCS/CNTH/DTE/CNTH IN CASI FIN 05/07/92 #1 6890.00-10010.00 1600BPI API#500292225600 8626->TP# ~ If you have any SCH REF#92302 Information Control Well Records Adrian J. Martin /,J RECEIVED JUN 11 1992 Alaska Oil & Gas Cons. Commission Anchorage ' ' AOGCC GEOLOGICAL MATERIALS INVENTORY' LiST [ check off or list data as it is re~ceived cored inti~als core ,,ana, lysis , d~ ditch inte~¥als dil~ital data "' ,,, " LOG TYPE '" RUN INTERVALS " SCALE NO. 7] ~ - . ,,, ..... 9] 10] , , 11] , 13] i4] ..... ,, ...... , ..... 16] , , , , 19] i , i ii iii i i i i i i i lUllUlll BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 05/12/92 T# 83512 BP OPEN HOLE FINALS Enclosed is your. copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. DIL, PH~SOR / 05/07/92 #1 Hcs-- 0s/07/92 CNL / 05/07/92 #1 9302.00- 9950.00 SCH 1/2" 9302.00- 9950.00 SCH 2/5" 9302.00- 9918.00 SCH 2/5" 6900.00- 9899.00 SCH 2/5" Information Control Well Records Adrian J. Martin ,z// RECE VED Alaska Oit& Gas Cons, commission Anchorage TO: THRU: FROM: MEMORANDUM Sta e of Alaska ~ ALASKA OIL AND GAS. CONSERVATION COMMISSION Lonnie C DATE: May 13, 1992 Commissio FILE NO: lg513-3, doc Blair Wondzell P. I. Supervisor Louis R Grimaldi Petr Inspector TELEPHONE NO: SUBJECT: Rig/BOPE Inspection Nabor's Rig 28-E BPX #M-31 Permit 92-32 Prudhoe Bay Unit Thursdav,.Mav 7, 1992 I made a rig/BOPE inspection on Nabor's Rig 28-E which is drilling Well #M-31 in the E.O.A. of the Prudhoe Bay Unit for BPX. The rig and its surrounding area appeared to be in good shape with all equipment in place and operating. My inspection revealed three noncompliances, these being: the accumulator which had an internal hydraulic leak, this being evident when I looked inside the reservoir; the BOP stack had 1/2 inch threaded nipples and needle valves on the side outlets of the preventer bodies; and, the kill sheet had not been kept up to date although it should be noted that the driller had all pertinent information in his tally book, e.g., pump strokes and circulating pressure, current mud weight, and depths. James Carlisle (BPX Rep) was informed and will attempt to repair all items by his next BOP test which, is due May 13, 1992. In summary~ I inspected Nabor's Rig 28-E and found three noncompliances. Attachment 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 OPERATION: Drlg ~' Compl Location: Sec / T ///ti Drlg contr ~~-~, Location (gen'l) ~0{~ Wkvr U I C Ri g# ~ ~t~' Well sign y/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Rig/BOPE InspeCtion Report Representative Well name /~ Representat i ye. _/.. ~'..l~)~ I N COMPL I ANCE; ~es no n/.a A. D IVERTER 1. ( ) ( ) (~d~ line sz & length 2. ( ) ( ) (XO line conn& anchored 3. ( ) ( ) (~ bifurcated & dwn wind 4. ( ) ( ) gV~) 90~ targeted turns 5. ( ) ( ) 0<) vlvs: auto & simultaneous 6. ( ) ( ) (~.) annular pack-off 7. ( ) ( ) (~) condition B. BOP STACK 8. ~<) ( ) ( ) wellhead flg wkg press 9. ()~) ( ) ( ) stack wkg press 10. (X) ( ) ( ) annular preventer 11. ~ ( ) ( ) pipe rams 12. (~ ( ) ( ) blind rams 13 (~ ( ) ( ) stack anchored 14.~(j)<~.~' ( ) ( ) chke/kill line sz 15' ()~ ( ) ( ) 90~ turns targeted (chke & kill In) 16.~' ~(~, ( ) ( ) HCR vlvs (ehk~_~e & ~ 17. (X) ( ) ( ) manual vlvs (ehke & kill) 18. ( ) ~ ( ) connections (flgd, whd, clmpd) 19. ~. ( ) ( ) drl spool 200<) ( ) ( ) flow nipple 21. (k/~) ( ) ( ) flow monitor' 22. ~, ( ) ( ).' control lines fire protected · C. CLOSING UNITS .2~. CyJ' () 2s. (~) () 26. C~) () 27. (~) ( ) 28. ~) ( ) 29. ( ) 30. ( ) 31. (:x~ () ( ) wkg press ( ) fluid level ( ) oprtg press ( ) press gauges ( ) sufficient vlvs ( ) regulator bypass ( ) 4-way vlvs (actuators) ( ) blind handle cover ( ) driller control panel I N COMPL I ANCE; ~ no ~a 33. ~ ( ) ( ) firewail ) .b4 () 35.() 36. (~ ( ) 37. ~) ( ) 38. ( ) ~9. (>z) () 40. (~ ( ) ~. (~ () 42. ((~) ( ) 43 ( ) 45.~) ( ) 46 ( ) ~7. j;~ () ~9.(~ () so. s~. gX) () s2. (X) ( ) 53. J)(~ ( ) s4,() () ss. (~ ( ) s6.() () 57. ()(~' ( ) nitrogen power source (back-up) condition (leaks, hoses, etc) D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In corm trip tank E. R ! G FLOOR kelly cocks (upper,lower,IBOP) floor vlvs (dart vlv, ball vlv) kelly & floor vlv wrenches driller's console (flow monitor flow rate indicator, pit leve' indicators, gauges) ki 11 sheet up-to-date gas ~etection monitors (H-S & methan...e) hydr chke panel chke manifold F. MISC EQUIPMENT fl are/vent line 90 ° turns targeted {dwn strm choke lns) reserve pit tankage personnel protective equip avail all drl site suprvs trained for procedures H2S probes 32. (~)- ( ) ( ) remote control panel 58. (~K~ ( ) ( ) rig housekeeping ~ECQ~DS ~ Date of last BOP inspection: Date of last BOP test: C--~-~' Resulting non-compliance: ~on-compl~ancea no~ corrected ~ B~ge correcg~ons ~ill be compleg~: BOP test & results properly entered on daily record?,~S-- Kill sheet current? ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14.33 TELECOPY: (907) 276-7542 April 2, 1992 Karen M. Thomas BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit M-31 BP Exploration (Alaska), Inc. Permit No: 92-32 Sur. Loc. 2082'SNL, 606'WEL, Sec. 1, TllN, R12E, UM Btmhole Loc. 4935'SNL, 2140'WEL, Sec. 36, T12N, R12E, UM Dear Ms. Thomas: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may'be given by contacting the Commission petroleum field inspector on the North Slope Pager at 659-3607. David W.~Jonns~pn, Chairman Alaska Oil as Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill [:::]l,b. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-Ii Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE 57'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchora(3e. Alaska 99519-6612 ADL 28257 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2082' SNL, 606' WEL, Sec. 1, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 5050' SNL, 1950' WEL, Sec. 36, T12N, R 12E M-31 (34-36-12-12) 2S 100302630-277 At total depth 9. Approximate spud date Amount 4935'SNL, 2140' WEL, Sec. 36, T12N, R12E 4/8/.8E' ?.~, ,~,~c $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandTVD) property line ADL 28260 @ 344' feet M-12 @ 2000'/27.4' feet 2560 9945°MD/9150' TV/]eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 3soofeet Maximum hole angle ~9.6 o Maximum surface 3330pslg At total depth (TVD) 1~800'/4390Pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" Cond. 80' Surface 110' 110' ,, 17-1/2" 13-3/8" 68# L-80 Butt 2980" Surface 2980' 2923' 2090 cu fl Arcticlll/420cu fl 'G' ...... 12-1/4" 9-5/8" 47# NT80-S NSCC 9214" Surface 9214' 8514' 2150 cu fl CS 'G' 8-1/2" 7" 26# 13CR NSCC 978' 8964' 8297' 9942' 8571' 290 cu fl CS Neat 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorREEEIVED Surface Intermediate Production MAR 2' 6 3992 Liner Alaska Oil & Gas Cons. Commission Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'~ Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ,~7~- , Signed ..:::~? '.~.:~- ~'-~ .~ ~ Title PBU Lead Engineer Date. , . Commission Use Only Permit Number ]APl number ]Approval date See cover letter ~.2. - ,~.~L 15 O- ~ 2_ <~ - 2_ ~ ~ 5'-~ I ~'"',~ --- ~,~ for other requirements Conditions of approval Samples required [] Yes ,,'~I'NO Mud log required []Yes ~]~'No Hydrogen sulfide measures [] Yes-,.1~[' No Directional survey requ~recl "~Yes [] No Required working pressurg-~e~.,,E 1-12M; 1-13M; J~5M; I-IIOM; I-I15M; Other:~ -~---~~,~~~~------'---'~ ' ' ' ' by order of Approv~,.~ % ~ Commissioner [ne commission Dates,,//~//~~ Form 10-401 Rev. 12-1 )- Submit PRELIMINARY WELL PLAN Well: M-31 [34-36-12-12] PBU LOCATION: Surface: Target: T.D.: 2082' SNL, 606' WEL, Sec. 1, T11N, R12E 5050' SNL, 1950' WEL, Sec. 36, T12N, R12E 4935' SNL, 2140' WEL, Sec. 36, T12N, R12E ESTIMATED START: April 8, 1992 OPR. DAYS TO COMPLETE: 22 (17 days drilling, 5 days completion) CONTRACTOR: Nabors 28E MAX ANGLE/SECT COURSE/KOP/BUILD RATE: 29.60/ N 30.2° W/3500'/2.5 Item TVDs$ MDi'BKB) Mud Wt. 20" CONDUCTOR 13-3/8" SHOE BASE WEST SAK FORMATION 9-5/8" SHOE TOP SAG RIVER SANDSTONE CURRENT GCC TOP SADLEROCHIT TARGET TOTAL DEPTH 80 8.5 2923 3OOO 9.5 5310 5529 9.0 8514 9214 9.7 8515 9215 8.4 Above Sad 8.4 8639 9357 8.4 8759 9496 8.4 9150 9945 8.4 LOGGING PROGRAM: Open Hole - Record all logs on magnetic tape where applicable. 12-1/4" Hole: None 8-1/2" Hole: DIL/CNL/GR/SP/SDT, Optional: LDT/GR, RFT Cased Hole Gyro survey after rig release. SS: 3/20/92 RECEIVED MAR 2 G 1992 Alaska 0il & Gas Cons. Commission Anchorage PROPOSED DRILLING AND COMPLETION PROGRAM WELL M-31 [34-36-12-12] PBI,I Install and cement 80' of 20" conductor to surface. Diverter system will be installed. The Drilling fluid program will consist of an 8.5 - 9.5 ppg spud mud in the 16" hole, a 9.0 - 9.7 ppg water base mud in the 12-1/4" hole and an 8.4 ppg water based mud in the 8-1/2" hole. Drill 16" hole to 3000'. Run and cement 13-3/8", 68 #, L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. A formation leak-off test will be performed 10' below the 13-3/8" shoe. Directionally drill 12-1/4" hole to the 9-5/8" casing point above the top of Sag River Sandstone. Run a 9-5/8" casing string to within 10' of 12-1/4" TD and cement with Class G cement around the 9-5/8" shoe. The annulus will be freeze protected by crude oil. Directionally drill the 8-1/2" hole to TD. Run 7" liner from TD to 250' inside 9- 5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to NaCI completion fluid. Test casing and lap to 3500 psi. Run 9-5/8" production packer on tubing. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with Diesel from surface to 2300' TVDBKB. Set and test packer. The well will be perforated after the rig has been released. Fluids incidental to the drilling of a well will be pumped down the 9-5/8" x 13- 3/8" annulus of the well. Tubing Size: 5-1/2", 17 # NT13CR-80, NSCC tubing with 6 GLM's. SS: 3/20/92 RECEIVED MAR 6 1992 A)aska Oil & Gas Cons. Commission An~hnrnnn MUD WEIGHT WELL M-31 CALCULATIONS (34-36-12-12) Mud Wt. (8-1/2" Hole): 8.4 ppg. P Sag River: P Sadlerochit: P Top Sadlerochit: 3550 psi. 3630 psi. at 8800' TVDSS 3570 psi. OB Sag River: OB Top Sadlerochit: Current GCC: 210 psi. 227 psi. Above Top Sadlerochit 9-5/8" Casing Pt. Top Sag River Top Sadlerochit 8571' TVDBKB 8572' TVDBKB 8696' TVDBKB Cement Calculations 13-3/8" CASING Measured Depth: Basis: Total Cement Vol: Lead Slurry Vol: Tail Slurry Vol: 2980' 2 X Annular volume 2500 (cu ft) 2090 (cu ft) 1075 Sx Arcticset III @ 1.94 Cu ft/Sk 420 (cu ft) 370 Sx class G cement @ 1.14 Cu ft/Sk 9-5/8" CASING Measured Depth: Basis: Total Cement Vol: Lead Slurry Vol: Tail Slurry Vol: 9214' 90% Annular Volume of 12-1/4" hole + 50 cu ft 2150 (cu ft) 2000 (cu ft) 810 Sx G+8% @ 2.75 Cu ft/Sk 150 (cu ft) 129 Sx Neat G @ 1.1 5 Cu ft/Sk Ugnu (shallowest hydrocarbon zone) will be covered by at least 500' of cement (at top). 7" LINER Measured Depth: Basis: Total Cement Vol: 8964' (Hanger) - 9945' (Shoe) 1.5 X Annular volume to 9-5/8" shoe + 150 cu ft 290 (cu ft) 250 Sx Neat G @ 1.16 Cu ft/Sk SS: 3/20/92 RECEIVED MAR ~ 6 199,2, Alaska 0il & Gas Cons. Commission Anchorage PF~_.~LIMINARY WELL PLA.~ WELL M-31 [34-36-12-12] PBU 20" Conductor PROPOSED DEPTH MD/BKB 110' Ball Valve 2100' 13-3/8" Casing 2980' 16" hole 3000' Top of cement in the 9-5/8" annulus is estimated at 3100' Note: This will provide at la minimum 600' coverage at the top of Ugnu (the shallowest hydrocarbon zone) 5-1/2" 17# 13Cr-80 NSCC tubing with GLM's 9-5/8" Packer 8914' 7" Tieback Assembly 8964' 9-5/8" Shoe 9214' 12-1/4" Open Hole 9224' 7" 26# 13 Cr-NT 80 NSCC Liner PBTD 7" Liner Shoe 8-1/2" Open Hole Alaska, Oit & Gas Cons. 'Anchorage 9865' 9942' 9945' SS 3/20/92 $45DUA247:[DRAN033]M31 MARK.LIS;1 19-MAR-1992 15:17 PRUDHOE BAY UNIT DRAN033 / 19-MAR-92 /15:17:29 MARKERS FOR WELL M-31 [34-36-12-12] ENGINEER: Saad Saleh Label TVD TVD MD DEPART INC SS (BKB) BASE PERMAFROST 1840. 1897. 1897. 0. 13 3/8" SHOE 2923. 2980. 2980. 0. 16" HOLE 2943. 3000. 3000. 0. KOP #1 3443. 3500° 3500. 0. TOP UGNU SANDS 3625. 3682. 3682. 7o END OF BUILD ~1 4575. 4632. 4684. 299° BASE WEST SAK FORMATION 5310. 5367. 5529. 716. IKRU-PBU 6680. 6737. 7105. 1494. PACKER 8253. 8310. 8914. 2388. TOP 7" LINER 8297. 8354. 8964. 2413. 9 5/8" SHOE 8514. 8571. 9214. 2536. TOP SAG RIVER SANDSTONE 8515. 8572. 9215. 2536. 12 1/4" HOLE 8523. 8580. 9224. 2541. TOP SHUBLIK FORMATION 8554. 8611. 9260. 2559. TOP SADLEROCHIT 8639. 8696. 9357. 2607. TARGET 8759. 8816. 9496. 2675. CURRENT OWC 8890. 8947. 9646. 2750. TOP HOT 8971. 9028. 9739. 2796. ORIGINAL OWC 9020. 9077. 9796. 2824. TOTAL DEPTH 9150. 9207. 9945. 2897. KAVIK (BASE SADLER) 9187. 9244. 0. 0. TOP EILEEN SANDSTONE -1. 0. 0. 0. CURRENT GOC -1. 0. 0. 0o ANGLE 0.00 0.00 0.00 0.00 4.55 29.59 29.59 29.59 29 59 29 59 29 59 29 59 29 59 29 59 29 59 29 59 29 59 29.59 29.59 29.59 0.00 0.00 0.00 Page $45DUA247:[DRAN033]M31 CLOSAP SHORT.LIS;1 Search Radius= 200 COURSE LINE For proposed well: M-31 [34-36-12-12] Location = W-E $-N TVD(SBS) Top 628214.00 5974274.00 -57.00 Bottom 626703.16 5976770.98 9187.00 Note: Ail depths in feet Below Kelly Bushing (BKB) 19-MAR-1992 Closest Approach Analysis --- Date: 19-MAR-92 Time: 14:52:55 14:53 WELL IDENT A029-2010500 M-4 A029-2036700 M-6 A029-2051200 M-14 A029-2052200 M-13 A029-2056700 M-10 A029-2058900 M-11 A029-2059300 M-12 A029-2061200 M-15 A029-2061300 M-16 A029-2085500 M-TW A029-2089700 M-19 A029-2093600 M-22 A029-2093700 M-23 A029-2200400 M-26 ( Closest Approach /PROPOSED~ /NEARBY~ TVD DEPART TVD DEPART CLOSEST DISTANCE 3879 .0 1943.0 2001 .0 1.3 4.7 3 2 2001 8 4648 3 1104 7 4430 8 5310 5 4468 6 NO COORDINATE 5000 .7 31.9 0.0 0.0 0.0 0.0 0 0 0 0 308 3 0 0 198 1 684 4 214 7 3888 1941 1999 0 0 0 2000 4641 1100 4360 5072 4599 POINTS WITHIN 508.5 670 .3 335.0 30 .6 0 0 0 0 0 0 9 8 15 7 1 4 1151 8 1318 8 761.4 184.4 488 2 231 7 145 0 185 0 75 1 27 4 197 8 474 8 240 1 596.3 285.6 SPECIFIED SEARCH WINDOW 4996.4 1083.7 318.1 Vertical /PROPOSED~ TVD DEPART Intersection /NEARBY~ TVD DEPART VERTICAL DISTANCE 4517.1 238.7 3550.8 134.3 -965.1 4648.1 308.2 3850.9 977.2 -795.4 7590.0 1979.1 6218.7 2244.9 -1377.1 SUMMARY The well which comes closest to the proposed well is: A029-2059300 M-12 Closest approach distance = 27.4 feet $45DUA247:[DRAN033]~31 CLOSAP SHORT.LIS;1 19-MAR-1992 14:53 Page 2 KICK OFF for this run = 3500.0 feet $45DUA247:[DRAN033]M31 CLOSAP SHORT7.LIS;1 Search Radius= 200 7 DEGREE LEAD LINE For proposed well: M-31 [34-36-12-12] Location = W-E $-N TVD(SBS) Top 628214.00 5974274.00 -57.00 Bottom 626410.12 5976568.24 9187.00 Note: Ail depths in feet Below Kelly Bushing (BKB) 19-MAR-1992 Closest Approach Analysis Date: 19-MAR-92 Time: 14:56:07 14:56 Closest Approach WELL IDENT /PROPOSED~ /NEARBY~ TVD DEPART TVD DEPART A029-2010500 M-4 3869.0 A029-2036700 M-6 1943.0 A029-2051200 M-14 2001.0 A029-2052200 M-13 1.3 A029-2056700 M-10 4.7 A029--2058900 M-il 3.2 A029-2059300 M--12 2001.8 A029--2061200 M-15 4601.2 A029-2061300 M-16 1104.7 A029--2085500 M-TW 4572.1 A029-2089700 M-19 5189.6 A029-2093600 M-22 4500.4 A029-2093700 M-23 NO COORDINATE A029-2200400 M-26 ( 5086.8 CLOSEST DISTANCE 30.4 0.0 0.0 0.0 0.0 0.0 0 0 282 3 0 0 266 5 615 7 230 4 POINTS 557.4 3881.2 1941.7 1999.6 0.0 0.0 0.0 2000.0 4594.8 1100.0 4502.7 4982.6 4632.7 663.7 335 0 30 6 0 0 0 0 0 0 9 8 15 3 1 4 1199 6 1241 8 791 5 186.5 488.2 231 7 145 0 185 0 75 1 27 4 233 9 474 8 219 8 648 9 286 4 WITHIN SPECIFIED SEARCH WINDOW 5052.2 1151.6 253.5 Vertical /PROPOSED~ TVD DEPART Intersection /NEARBY~ TVD DEPART VERTICAL DISTANCE 4598.9 281.1 3694.7 186.9 -903.0 4670.8 321.1 3966.8 1017.6 -702.2 9023.2 2793.1 7389.5 3108.0 -1639.5 SUMMARY The well which comes closest to the proposed well is: A029-2059300 M-12 Closest approach distance = 27.4 feet BOP STACK CONFIGURATION 13 5/8", 5000 PSl WP TRIPLE RAM ,STACK DRILLING RISER ANNULAR PREVENTER 2" KILL LINE MANUAL HYDRAULIC GATE GATE t, , PiPE RAMS 1 BLIND RAMS ,/ ,1 , , , DRILLING SPOOL I P l PE RAMS 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE MAR 2 6 1992 Alaska a~! & Gas Ccno,-'~mmissior~ Anchorage TO FI. ARE CAVIEM UNIT I CAYIEM UNIT 2 CHOKE MANIFOLD TRIP TANK 170 BBL VOLUME TANK 137 BBL VOLUME TANK 180 BBL ITO DISTRIBUTION WATER ~ 87 BBL FILL LINE .S~ND TRAP 4 BBL 131BBL DISTI DITCH 81 BBL DEGASSING TANK EQ. SUCTION 117 BBL DESILTER NABORS CI~NTRIFUGI~ PIONEER MI( I TO PiT DEQA88ER DRLCO 8EEFLOW TO STAND PIPE KILL LINE MUD PUMPS MUD HOPPER8 & MIXING PUMP8 SUCTION 134 BBL NABOR$ DRI.I.J~IG LTD' RIG No. 28E MUD SYSTEM SURFACE FAClLITES TOTAL ACTIVE SYSTEM: 800 BBL TOTAL SURFACE CAPACITY : 970 BBL ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru 8] 3. 4. '[9t4 '3] ~ [10 & 131 (4) Casg ~.~,~, ,L [ 14 thru (5) BOPE [23 thru 28] [29 thru 31] (6) Other (6) Addl 5~ 6 7 8 . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Lease & Well 0, zd~/~& YES NO Is sufficient undedicated acreage available in this pool ............. ~_ Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait.., ......................... . Does operator have a bond in force ................. ' ................. ~ Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ngrnber appropriate .......................................... L Does well have a unique name & n~nber ................................ '~_ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... ../_.~_~ Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... · , Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. /? Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams g descriptions of ct~=~~-~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ,~-~¢opsig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLOP~ATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. REMARKS i / / / ./ geology' en9 i neer i ng~. DWJ::~ MTM ,~ff.,~ LCS RPC, z~ BEW ./~ RADqD fl--1 rev 03/29/91 jo/6.011 INITIAL GEOI UNIT ON/OFF POOL CLASS STATUS AREA SHORE Additional remarks' 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ****************************** *'"''''' SCHLO~OERGER ~E[.,I.~ NAME : M 31 (34.-36-12"12) DHOE BAY OOPOUGM : NORTM SLOPE STATE : ALASKA API NUMBER : 50-029~22256-00 REFERENCE NO : 92]02 RECEIVED JUN 1 1 1992 Alaska 011 & Gas Cons. Commission Anchorage IS Tape Verification Listinq chlumbergerA!asKa Comput,tnq Center 2!-MAY-!992 06:32 SERVICE NA~E : EDIT DATE : 92/05/~6 ORIGIN : FLIC REEL NAME, : 92302 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION,PRUDHf~E BA¥,~-3t,50-029-2226600 **** TAPE }~EADER SERVICE NA~E : EDIT D~TE : 92/05/16 ORIGIN : FbIC TAP~ NAME : 92302 CONTINUATION PREVIOUS TAPE : COMMENT : BP EXPLORATION,PRUD~fOE BAY,~-31,50-029-2226600 TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE ~;'IRELINE LOGS WEL~ NAME: API NUMBER: OPERATOR: L~G~!NG COgPANY~ TaPE CREATION 0 TE: ~OB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: FSL: ELEVATION(ET FRO~ ESL O) KELLY BUSHING: DERRICK FLOOR: GROUN~ LEVEL: WELL CASING RECOP~ STRING STRING 92302 T, WEST J, CARLILE ~' 31 (34'36'12'12) 500292225600 BP EXPLORATIO~;i SCHLUMBERGER ~ELL SERVICES 1 b'MA Y-92 t0 lin 12E 2082 6O6 57 O0 56i00 26 O0 OPEN HOLF CASI~G D~ILLERS BIT SIZE (IN) SIZE CIE)DEP'T'.. H (FT) '''8.500 ........... P h G E ~, IS Ta~e Verif~.cation bastI g .'h!um..erger Alaska Computl~q Center 2!-~AY-!g92 06:32 3RD STRING PRODUCTION STRING REMARK ' ,.S, FIELO fNGINEER'S RE~ARKS' TOOL STRING (BOT-TOP): ~iTE-SLTT-CNTR-SGTL-TCCB-A~S N~UTRON MATRIX = SANDSTONE, HOLE CORRECTION CNb RU~ WC~H A 8[W~PR.ING, .4 T~FbON STANDOFFS, SONIC.. WIT}~ 1,5" DITE RUN W~TH 1 " MAX!MUM DEVIATI ~ ...... ~ON 35.0 AT5 11 MD. AFTER ~OG SONIC CHECK IS SEED AT END OF MAIN PASS, CNL RUN IN CASING WITH B~S = CASE. NO BP× GEOLOGIST ON LOCA~'ION FOR WITNESSING LOGS. $ $ PAGE: **** FILE }!FADER **** FILE NAME : EDIT ,00! SERVICE : FbIC YERSiON : O01A07 DATE : 92/05/~6 MAX RFC SIZE : !024 FI'bE TYPE : LO ~AST FILE FILE HEADER FILE NUMBER: 1 EDITED CURVES Alt tOO1 strlnos: DePth shifted amd clipped curves; all runs merged; no cased holedata,, DEPT~ INCREMENT 0.5000 # FILE SUMMARY TOOL CODE START DEPTH $~OP DEPTH GR 9R91.0 9]02.0 BCS 991g.0 DTE 9950.0 930~,0 CMTH 9899.0 9302,0 $ BAS~LINE CURVE FOR SHIFTS: GR.BCS CURVE SHIFT DATA (MEASURED DEPTH) BASELIN~ DEPTH 9874.0 9873,5 9859,0 9829.0 9827,0 9824.5 22,0 ~,0 ----------EQUIVALENT UNSHIFTED DEPTH ...... ---- PT SFL DTE CMTH 88888. . 88888.5 88888.0 9874,0 9859.5 9829.0 9R27.5 g824.5 9822.0 9814.5 IS Tape Verificatiom Listing cblumberger AlasKa Computing Center 21-~AY-1992 06:32 9804 9'789 9745 9744 g744 732 973 97!~ 97 9635 9597 9596 9575 9567 9559 9542 9540 95~9 9475 9473 9473 9427 9416 9414 94!.4 9413 9394 9393 9386 93 ~ 9379 5 9803,5 0 9788,5 0 5 9744.0 0 9744,5 5 9732.0 5 9732,0 O 5 9715.0 0 9715.0 5 9635,5 0 9~96,5 9596.5 i 9574,0 5 9566.:5 5 5 9542'5 5 .0 0 ,... 9473,0 9473,0 '5 9414.O .5 ,5 9394.5 .0 9386,5 0 9381,5 ,0 9381.5 .5 9373 0 9374:5 9363:5 9364:0 9340'5 9339.5 93~7,5 9326.0 9325,0 9325 5 93~5.0 9302:0 9302.0 9301 5 924'~i5 9187 0 100 0 100,0 99.0 $ N~RGED DATA SOURCE PBU TOOb CODE RUN NO, PASS RE~aRKS: THE DEPT~ ADJUSTMENTS S~OWN GR.BCS, SFL.DTE TO GR.OCS, 9744,0 9744,5 9715,0 9596.0 9559.5 9539.5 9473,0 9473,0 9425.5 9414':5 9412,0 939~,0 9394.5 9381,5 9375,:0 9325.0 9303.5 9241.0 9186.0 1.02.0 99.0 ~RGE TOP ABOVE ~EFLECT DT.BCS TO SP.DTE (& ALL DTE CURVES) TO IS Tane verification Listing chlum~erger AlaSKa Computing Center 21-~A¥-!992 06:32 GR.BC8, & NPHI,CNTH TO GR.BCS. $ FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE -64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 8O 4 66 ! 5 66 6 73 7 65 8 68 0,5 9 65 FT i! 66 12 i2 68 13 66 0 14, 65 FT !5 66 68 !6 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP/ AP1 FILE NUMS NUMB SiZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548255 O0 000 O0 0 1 1 1 4 68 DT BCS U$/F 548255 O0 000 O0 0 ! I I 4 68 GR BCS GAPI 548~55 O0 000 O0 0 1 1 1 4 68 TENS BCS LB 548255 O0 000 O0 0 l 1 1 4 68 TE~D BCS LB 548255 O0 000 O0 0 I 1 1 4 68 IDPH DTE OHMM 548255 O0 000 O0 0 1 1 i 4 68 IMPH DTE OHM~ 548255 O0 000 O0 0 I ! I 4 68 ILD DTE OH~ 548255 O0 000 O0 0 1 1 1 4 68 IL~ DTE OHM~ 548255 O0 000 O0 0 1 1 1 4 68 SP DTE ~V 548255 00 000 00 0 ! I 1 4 68 SFL DTE 548255 O0 000 O0 0 I ; 1 4 68 ~TE~ DTE DEGF 548255 O0 000 Oq O 1 1 1 4 68 ~RE$ DTE OHM~ 548255 O0 000 00 0 ! 1 ~ 4 68 NPHI CNTH PU-S 548255 O0 000 O0 0 1 1 ] 4 68 N~AT CNTH 548255 O0 000 O0 0 I 1 1 4 68 C~AT CNTH 548255 O0 000 00 0 1 1 1 4 68 NCNT CNTH CPS 54~255 O0 000 O0 0 1. ! 1 4 68 FCNT CNTH CPS 548255 O0 000 O0 0 I 1 ~ 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0O0O0O0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Tame Ver!ficatton LiSting chlumberger AlasKa ComPutiD~ Center 2!-~AY-1,992 PAGE: NA~. SERF UN SERVICE .... Pl API FI E NUMB N!J~8 $ R~OCE$6' ~'' :ID ORDER # bOG TYPE ' ....... P · CLADS ~DD NUMB SAM. ELE~i CODE (~EX) C.NTC CNTH CPS 548255 00 000 O0 0 1 1 I 4 68 0000000000 CFTC CNT~ CPS 548255 O0 000 O0 0 1 1 i 4 68 0000000000 DEPT. 9950.000 ~D BCS -999.250 TEN ...... , . 863 MgES,DT~ 0,250 NCNT.CNTM "999, DMPT. 9500.000 T~ND,BC$ 900.500 L~.DTM 22.885 ~RES.DT~ ~ NCNT.CNTH 275 ,847 .375 DEPT. 9302,000 TEN~ BC$ 974,000 !L~:DTM 1950,000 ~.iS.DT~: 0.854 NCMT.CMTH 32.37,500 ** END 07 DATA ** DT BCS IDPH DTE SP DTE NPHI CNTH FCMT CNTH DT,BCS IDP}{,DTE SP,DTE MPHI CNTH FCNT:CNTH DT.BCS IDP'H DTE ,DTE NPHI,CNTM FCNT.CNTM -999 250 4 629 -93 3-999 ~50 32: 0 -160.777 25. 7 GR.OCS -999.250 TENS.BCS 566 ILD DTE I~P~,DTE 6, . SFL,OT~ i5,172 MTE~.DTE NRAT,CNTU 99 ~50 CRAT C~:rM CNTC.CMTH 99:250 CFTC:CNTM 76.813 GR.BCS 74,~25 TENS,BCS 1950,~00 IMPH,DTE 195o, O0 IbD,DTE -~25, ~5 SFL.DTE 20,484 MTE~,DTE 1.6,~ 3 NRAT.CNTR ! 937 CRRT.CNTH 1541. 50 CN.C' T .CNTH 3i45:250 CFTCiCNTM -999.250 4.582 175,375 -999,250 -999.250 5135,000 30.469 173.199 2,449 I112,313 5075 000 1950~000 168,000 8 8 **** FILE TRAILER **** FILE NAME : EDIT ,OOl 6ERVICE : FLIC VERSION : O01A07 DAT~ : 92/05/~6 MAX AEC SIZE : t0~4 FILF TYPE : LO LAST FILE : **** FILE HEADER F!LF NAME : EDIT .002 SERVICE : FLIC VERSION : O0~A07 DATE : 92/05/16 MAX AEC $IZ~ : 1024 ~'ILF TYPE : LO LAST FILE : IS Tame Verification List~ q chlumberger AlasKa comput ~q Center 2! ~,~AY-~.99P 06:32 FILE HEADER FILE NUMBER: 2 EDITED CANED HOLE MAIN PASS Depth shifted and clip.~ed curves for open bole loqs run into casing. 3 0,5000 DEPT!~{ INCREMENT FILE SUMMARY PBU TOOL CODE ~CH CNT8 START D.~P:.tH STOP DEPTH 9302,0 68 ,0 BASELINE DEPTH ~B~88.0 9307,5 9304,0 9:286,5 9284 0 9247 5 9240 5 9~!9 0 $ REMARKS: CURVE SHIFT DATA (MEASURED DEPT}~) PASS NUMBER: 1 ----"----'EQUIVALENT UNSHIFTED DEPTH----=----- GRCM 88887.5 9304,0 9286,5 9254,S 924~.,5 924 ,0 9220,0 CNb Ri!N IN CASING WITH EHS : CASE, $ # LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TY REPR F V' I 66 0 2 66 0 3 73 44 4 66 5 66 6 73 7 65 @ 68 0,5 9 65 FI' 11 66 23 chlumberger Ala ~a ComPUt: nq Center 21-"AY- ~.~ ,. I992 06:32 PAGE': mmm~m DEPT GRCH CNTH NPH. I CNTH NRAT CNTH CRAT CNTM NCNT CNTH FCNT CN'TH CNTC CNTH FTC CNTH TEND CNTH TYPE REPR CODE VALUE :I 2 68 13 66 0 14 65 FT 15 66 68 !6 66 0 .66 ! SET GAP! PU-S YPE- CMAN ** RVICE PI API A API FILE NUMB B SIZE RE ES~ T ORDER # 546255 O0 000 O0 0 548255 O0 000 O0 0 548255 O0 000 O0 0 548.255 O0 000 O0 0 548255 O0 000 O0 0 548255 O0 000 O0 0 546255 O0 000 O0 0 ~4~255 O0 000 O0 0 54~255 O0 000 O0 0 548255 O0 000 O0 0 000 O0 0 bOG TYPE CLASS ~OD NL1MB SAMP ELEM CODE (HEX) CPS cps CPS CPS LB LB 548255 O0 mm#mmmmm~m,~m 2 1 1 4 68 0000000000 2 I ! 4 68 0000000000 2 ! 1 4 68 0000000000 2 1 1 4 68 0000000000 2 1 I 4 68 0000000000 2 1 I 4 68 0000000000 2 1 I 4 68 0000000000 2 i' 1 4 68 0000000000 2 1, I 4 68 0000000000 2 1 I 4 68 0000000000 2 1 1 4 68 0000000000 mm~mmmmmmmmmmm#mmmmimmmm,~mm#mmmmmmmmmmmmmmmm ** DATA DEPT. CRAT,CNTH CFTC.CNT~ DEPT. CRAT CNTH cFTc:c~TH DEPT CFTC,CNTH DEPT. C~T,CNTH CFTC,CNT~ DEPT CRA?:CNTH CFTC,CNTH 9302 2 1455 9000 3 365 8500 322 ~000 4 354 7500 4 339 ,000 GRCH.CNTH 74 ,1.41 NCNT,CNTH 3301 .352 TEN$.CNTH 5200 ,000 GRCH'CNTM 65 956 NCNT,CNTM 1321 ~896 TENS,CNTH 5075 ,O00 GRCH,CNTH 57 ,667 NCNT,CNTH 1364 ,125 TENS,CNTH 4725 ,000 GRCH,CNTM ~3 ,398 NCNT.CNTH 1490 ,697 TENS,CNT~ 4545 000 GRCH.CNTH 56 :367 NCNT,CNTH 1333 ,130 TEN$,ChT~ 4490 63 NPHI,CNTH 15,.017 NRAT.CNTH ~74 FCNT,C..THN ~ 1350~62! CNTC.C~TH ,000 TEND,CNTH 997.000 6~8 NPH!,CNTH 46.550 NRAT,CNTH 517 FCNT,CNT~ 330,634 CNTC,CNT~ 000 TEND,CNTB 988,500 ,313 NPHI.CNT~ 59 509 NRAT.CNT~ ,717 FCNT,C.NTH 294~162 CNTC.CNTH ,000 TEND.CNTH 974,500 .594 NpHI.CNTH 54 613 NRAT.CNTH ,4~4 FCNT,CNTh 270~363 CNTC.CNTH .000 TEND.C~TH 1012.500 250 NPHI CNTH 54 037 NRAT.CNTH :47! FCNT:CMTM 305:572 CNTC,CNTH ,000 TEND,C~T~ 1132.000 2.352 3086.536 4160 1421:181 5.381 1425.294 3,852 1457,382 4,227 1440,886 IS Tape Verification Listing chlumberger AlasKa Computin..o DEPT CFTC,CNTH 7000,000 4 06 GRCH.CNTM MC~T,CNTH TE~$. C T~ DEPT'cNTH CRAT, CFTC.,CNTH 6890. 000 3 8 7..3 4 2 ** END OF DATA ** 21-~AY-tg92 06:32 108.625 !477.177 4280.000 4:7. 500 !53~ .897 4375 . 000 N P H i. C b! T H TElt 0, CNTH MPHI.C~TH f~.NT CNTM TE~N [). CNTH 5 i i 14 270 363 I i, .47 000 42,374 1235,000 NRAT. C~ ........ CNTC.CNTH NRAT CNTH PAGE: 4,550 1402.789 4,269 1508,9~4 **** FILE TRAILER **** DATE : 92/05/16 ~AX REC SIZE : 10~4 FILE TYPE : bO **** FILE HEADER **** FiLE NA~E : EDIT ,003 SERVICE : FLIC VERSION t O01A07 DATE : 92/05/16 ~AX REC SIZE : !024 FILE TYPE : LO bAST FIL~ : FILE HEADER FILE NUMBER 3 RAW OPE~ HOLE MAIM PASS Curves and loo header data for each.run and tool string in separate files; Tool String #1 fo Sad!eroch~t rdn presented first (p~lmary deptD control string used to depth s~ift t~e Sadler lnterval) followed bV files for other maln pass strings Per run, RUN NUMBER: 1 TOOL STRING NUaBER: 1 PASS NUMBER: 1 DFPTH INCREMENT: 0.5000 F~ILE SUMMARY VENDOR TOflb CODE START DEPTH DT~ 9950,0 CNTH 9899,0 L~G HEADER DATA S%~OP DEPTH 9183,0 9~83.0 9183,0 IS Tape Verlflcatlon bistlno cblumberqer AlasKa ComPutinO CeDter 21-MAY-1992 06;32 DATE bOGGED: SOFTWARE VER$ION~ TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOm: TD DRILI~ER TQ LOGGER{FT): TOP bOG INTERVAL (FT); BOTTOM bOG INTERVAL LOGGING SPEED (FPHR): T~LE GR DTE DTE STRING {TOP TO BOTTOM) TOO~ENDOR TOOL CODE TOOL~ TYPE AUX!LbARY SEAS, SONDE TELEMETRY CARTRIDGE GAMMA RRY $OU~C~ BOREHOLE SONIC CART. BOREHOLE S[~NIC SOND~ DUAL INDUCTION CART, DUAL .INDUCTION SONDE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH ~FT): LOGGERS CASING DEPTH (FT); BOR~HOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G); MUD VISCOSITY (SI: PH: FLUID LOSS (C]): MAXIMUM RECORDED TEMPERATURE [DEGF): R~S~STIVITY (OHMM) AT TEMPERATURE (DEGF): MU[) AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT)~ MUD FILTRATE AT (MT); MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT NEUTRON TOOL TOOL TYPE (EPITHERM~b OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STANDOFF (IN): RE,ARKS: 07-~AY-9~ CP 32.6 !500 07-MAY-92 2055 07-MAY-92 9945.0 9958.0 6900,0 9899.0 1800.0 TOOL NUMBER AMM AA 950 TCC-B 840 SGC-$A 40 SLC-(IA 136 DIE 0 8,500 9295.0 9.302, LSND 8.80 41.00 9,70 6 30 2,400 78.0 2,310 78.0 3,280 78.0 SANDSTONE 2.65 TOOL STRING (SOT-TOP): DITE-SbTT-CNTH-$GTL-TCCB-AMS NEUTRON MATRIX = SANDSTOC~E. hOLE CORRECTION = SS. CNL RI.IN WOTH A BC)WSPRING. OITE RUN WITH 1.4" TEFLON STANDOFFS, SONIC WITH 1.5" ~AXIMU~ DEVIATION ]5.0 AT 5~11 ~D, IS Ta~e Yeri~ficatlon Listlnq Ska Computiuq Center Chtumberqer 2J-~AY-1992 06:32 AFTER hOG SONIC CMEC~i IS SE~N AT,END O.F MAIN PASS, CNL RUN'IN CASING~irM BHS': CASE' NO BPX GEOLOGI.ST ON'LOCAl<ION ~OR ~ITN'ESSlNG LOGS, $ L!8 FORMAT DATA PAGE{ I0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64E~ ** TYPE REPR,CODE VALUE 1 66 0 2 66 0 3 73 192 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1! 66 5 12 68 13 66 0 ~4 65 FT 15 66 16 66 1 0 66 ** SET TYPE - CMaN ** NA~K SERV UN1T SER¥ICE APi API AP1 API FILM NO~fl NUMB SIZE RMPR PROCESS ID ORDER ~ bOG TYPE CLASS MOD NUmB SANP ELEN CODE (HEX) mm~mmmmmmmmmmmmmm~mmmmmm~mmmmmmmm~mmmmmmm~mmmmmmmm~mmmmm~m~mmmmm~m~mmmmmmm~mmm~mm~ DEFT FT 548255 O0 000 O0 0 3 ! 1 4 68 0000000000 DT BHC US/F 548255 O0 000 O0 0 3 1 1 4 68 0000000000 TT! BHC US 548255 O0 000 O0 0 3 1 I 4 68 0000000000 TT2 BHC bS 548255 O0 000 O0 0 3 1 I 4 68 0000000000 TT3 BbC US 548255 O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BHC US 548255 O0 000 O0 0 3 1 1 4 68 0000000000 SP BHC ~V 548255 O0 000 O0 0 3 1 I 4 68 0000000000 G~ BHC GAPI 5q8255 O0 000 O0 0 3 1 ! 4 68 0000000000 T~NS B~C bB 548255 OO 000 O0 0 3 1 I 4 68 0000000000 STEM B~C DEGF 548255 O0 000 O0 0 3 1 ! 4 68 0000000000 ~RES BBC O~M 548255 O0 000 O0 0 3 I I 4 68 0000000000 ~TE~ BHC GB 548255 O0 000 O0 0 3 1 I 4 68 0000000000 ClOP DTK MMHO 548255 O0 000 O0 0 3 1 I 4 68 0000000000 IDF~ DTE !3[~M~ 548255 O0 000 O0 0 3 1 1 4 68 0000000000 CTNP DTE ~HO 548255 O0 000 O0 0 3 1 I 4 68 0000000000 IMPH DTE OHMS 548255 O0 000 O0 0 3 t i 4 68 0000000000 IS Tape verification Listtn:q chlumberqer Alaska ComDutfng Center 21-NAY-1992 06:32 PAGE: II ORDER # bO., TYPE CLA S MOD CtLD DTE M~HO 548255 O0 000 O0 0 ILD DTE O,HMM 548255 00 000 O0 0 CIL~ DTE ~MMO 548255 OO 000 O0 0 IL~ DTE [3H~M 548255 OO 000 00 0 IFRE DTE HZ 548255 O0 000 00 0 IDQF DTE 548255 00 000 00 0 I~OF ~TE 548255 O0 000 O0 0 I!RD OTE NMNO 548255 00 000 OO 0 IIXD' DTE ~HO 548255 00 000 O0 0 IIRN DTE M~HO 5.48255 00 000 O0 0 IIX~ DTE ~MHQ 548255 00 000 00 0 SFLU DTE OHNM 548255 00 000 00 0 SP DTE ~V 548255 00 000 O0 0 GR DTE GAPI 54R255 O0 000 00 0 TENS DTE LB 548255 00 000 00 0 aTE~ DTE DEGF 548255 O0 000 00 0 MRE$ DTE OHM~ 548255 00 000 00 0 MTEN DTE b~ 546255 00 000 00 0 NPMI CNL PD 548255 00 000 O0 0 RT~R CNL 548255 00 000 00 0 TNPM CML PU 548255 00 000 00 0 TNR~ CNG 548255 O0 000 O0 0 MPOW CML PU 548255 00 000 O0 0 RCNT CML CPS 548255 O0 000 00 O RCFT CNL CPS 548255 O0 000 00 0 CNTC CNG CPS 548255 00 000 OO 0 CFTC CNL CPS 548255 00 000 00 0 GR CNL GAPI 548255 00 000 O0 0 TENS CNL LB 548255 O0 000 O0 0 ~RES CML OH~N 548255 00 O0O 00 0 ~TE~ CNL DEGF 548255 O0 000 00 0 HTEN CNb LB 548255 00 000 00 0 FIbE NUMB 3 3 3 3 3 3 3 3 3 NUMB NUmB SIZE SAM.P ELEN !. I 4 1 1 4 I I 4 1 I 4 1 i 4 1 I 4 1 I 4 1 1 4 1 1 I 1 1 1 4 1 1 4 1 I 4 ! ! 1 1 1 1 4 1 1 4 ! 1 4 1 1 I 4 I 1 4, 1 ! 4., I 1 4 I 1 4 1 1 4 1 1 I I 4 1 I 4 1 I 4 ! 1 4 REPR PROCESS CODE (HEX) 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 O8 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 65 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 DATA DEPT. 10010.000 DT.BHC 77.938 TT3.BHC 520.000 TT4 BHC 362 250 TENS,BHC 3020,000 MTEM:BHC 175[375 CIDP,DfE 216,625 IDPH.DTE 4,6~3 CILD.DTE 218,250 ILD,DTE 4.578 IFR~.DT~ 20 000 IDOF !~TE a 000 IIXD.DT£ 27~984 !IR~:DTE 140:375 SD.DTE -93.6~5 GR DTE 31.484 ~SS.DTE 0.863 HTENiD~E -66.1~8 ~NPH.CNL 27.~31 TNRA.CNG 2.555 RCF?,CNL g50,~65 CNTC,C~L 259@.]41 T~NS,CNL ]020,000 MRE$,C~G 0,80] TT1,BNC 510 750 TT2.BHC SP,BHC -63i625 GR.BHC MRE$.BHC 0 863 HTEN.BHC CIMP.DTE 146.500 IMPH,DTE CIL~,DTE 14~.750 IL~.DTE IMOF.OTE 2.000 IIRD.DTE IIX~.DTE 18.109 SFLU.DTE TENS,DTE 3020.000 MTEM.DTE NPHI.CNL 27.238 RTNR.CNL NPOR,CNL 27,431 ~CNT.CNL CFTC.CNG 1030.428 GR.CNL ~TEM.CNL 175,375 HTEN.CNL 356,750 31.484 -66,188 6,820 6,719 1 820 175 375 2:716 2616,471 31.484 -66,188 Tape Yeriflcatlon Lis~inq Chlumberger Alaska ComPutin~ Center ~Ep?, loooo,ooo ~,~HC 520',000 TENSoBHC 4785,000 . ' 625 IIXD:DTE 27,984 ~ SP,DTE '93,844 ~RE$. DTE 0,863 TNPH.CN5 ,27.431 RCFT.CNb 950~ 865 TEN'S.CNb 47~5,000 DEPT, 9500,000 Tt3'~HC 570,500 TENS,BHC 5135,000 CIOP.'DTE 32,875 CIB¢'DTB 34,53:1 IFRE,DTE 20,000 IIXD,DTE 4.555 SP~DTE -161.000 ~ES'DTE 0.850 RCFT.CNL 1044,069 ' ' S CNL 5135.000 2EN.,, . . DEPT, 9182,000 TT3.BHC ~.750 TENS,BHC 5 . ,000 CIDP DT~ 66.93~ C!~Di~T~ ~.6~5 I~r~.o~ 20 ooo IfXD.DTE -448:750 SP.~TE -122.625 BRES.DTE 0.945 TNPN.CNL 54.7~6 RCFT.CNL 293.50~ T[NS.CNL 5!95,000 ** EMD OF DATA ** DT,BHC TT4;B~C MTEM,BHC IDPH,OTE ILD~DTE IDOF..DTE I!R~'DTE GR'DTE ~TEN.DTE CNTCiC~b DT'BHC TT4~BHC MTEM,BHC IDPH.DTE ILD,DTE IDOF.DTE GR,DTE HTE~ DTE TNRA CNTC CN5 ~RES CNL DT.BHC TT4~BHC tDPH'DTE IbD.DTE IDOF.DTE IIRM.DTE Ga DTE MTEN:DTE NRA,C~L NTC.CNL MRE$,CNL **** FILE TRAILER **** FILE NA~E : EDIT ,003 SERVICE : FLIC VENSION : 00~A07 DATM : 92/05/16 MAX RFC SIZE : I024 FILE TYPE : LAST FILE 21-~AY-I992 06:32 77,938 .362.250 !75.375 4.613 4.578 3 00o 140 3'75 3~ 484 614 000 · ! 0,863 86.063 88,000 ~73.~50 ~30'406 28,922 o,ooo 44,844 3.3'2Ig 900.500 2,460 2725,:~6t O. :50 56 250 267:500 163.8~5 14"9 2 14.563 o 000 .33~'75o 57.8i3 1053.000 4 415 1.3~7~676 0.945 TT1,BHC SP,BHC ~RE~,BHC CtMP,DTE ClL~,DTE IMOF,DTE IIXa. DTE TENS.DTE NPMI.CNL NPOR.CML CFTC.CNP MTEM,CNL TTI,BMC ~RES,BHC C!MP,DTE mQF.DTE IIX~.DTE TENS.DTE NPHI,CNL NPOR,C~L C~TC.C~ ~TE~..CML TT!,.BHC SP.BHC MRE6.BMC CIMP.DTE CIL~.OTE I~OF.DTE IIXM'DTE TENS,DTE NPHI'CNL NPOR,CN5 CFtC.CNG MTEa,CNL o , 3 146.500 148.750 2,:000 4785.000 27,238 27.43! ~030,428 175,375 572,000 ~1.31,000 4~: 850 813 47.188 o'ooo 10.164 5i35.000 1t57.80~ 173.25~0 382.250 -92.625 0.945 -34i 50 0 000 1218i000 5195 000 59 968 323 42 163 75 TT2 BHC GRiBHC H~,BHC IMPH.DTE Ib~,DTE ~.FLU:,DTE MTEM,DTE RTMR,CNL RCNT'CNL GR°CN~ HTEM,CNL TT2,BHC GR,BHC HTEN.BHC IMPH.DTE IbM DTE IIRD:DTE 5FLU,DTE MTEM,DTE RTNR,CNL RCNT,CNL GR,C~L HTEN.CNL TT2,BHC GR,BHC HTCN,BHC IMPH.DTE ILm.DTE IIRD DTE SFL3:DTE MTEM.DTE RTNR,CNL RCNT.CNL GR.CNL HTEN,CNL PAGE: '12 356.750 31.484 614.000 0.820 6.7!9' 1:87,875 14'820 175 375 2 716 2616 47! 3t.484 614.000 390,250 ]3.219 900.500 20 906 21 172 30 734 27 297 173.250 2 456 2773!820 33 219 9O0 5O0 27t 500 57i813 1053 000 1950'000 1950.000 61438 41348 163875 1288.674 57.813 1053.000 I~ Tape Vetlf,!catlon Listinq chlumberqer AlaSka Computing Center 2!-~AY-199~ 06:32 PAGE: 13 FIL~ NAME : EDIT ,004 SER¥iCK : FSIC VERSION : 001A07 DATE : 92/05/!6 MAX REC SIZE : !0~4 F!SE TYPE : bO LAST FILE : FIL~ HEADER Curve~ add .~o~ header dat~ ~or ,ach pass, tool str~n~ and run ~n separate ~ile~. RUN N'U~BER~ 1 TOOL STRING NUt~BER: P~SS NU~BE~: 2 D ~PTH INCRE~ENT: 0.500~ FTLE VENDOR T~OL CODE START DEPTH BBC 9603.0 DTE 9603 0 C~.~H 9603:0 LOG HEADER DATA DATE bOGGED SOFT~ARE VERSION: TIME CIRCULATION E~DED: TI~E GOGGER ON 80TTOM: TD D~ILbER (FT) TD LOGGE~ (FT) TOP bOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT)~ LOGGING SPEED (FPHR) S ~OP DEPTH 9295.0 9295,0 9295,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE mmmmmmmmmmmmmmmm T~LE G~ BHC ~C DTE TEbEMETRY C RT IDGE DUAL I DOCTIO CART BOREHOLE AND CASING DATA OPEN HC)I.,E; BIT SIZE (IN): DRILLERS CASING DEPTH eFT): 07-MAY-92 CP 32.6 I500 07-~AY-92 2055 07-MAY-92 9945 0 9958:0 6900 0 1800.0 TOOL NUMBER AMM .A 950 TCC-B 840 SGC-SA ~0 SLC-OA 116 SLS-WA 2001 DIC 430 DIS 430 8.500 295 0 I'$ Tare ¥.riflcat! isting chlumberger AlaSk~a omPuting Center 2!-~AY-1992 06:32 LOGGERS CASING DEPTH (FT) # ~O..P.. EMOLE CONDITIONS MUD TYPE: DENSITY (LB/G): MUD VISCOSITY ($}: MUD PH: FLUID bOSS (C3)~ RESISTIVITY (OHMS) A~'~E~pE~A. TURE (DL~GF) MUD AT MEASURED TE~PE.RA%URE (~T) MUD AT BOTTOM HOLE ~I..~D FILTRATE AT (MT) '~[~D FILTRATE AT '~{UD CAKE AT :,;.UD CAKE AT (BHT3 NEUTRON TOOL TOD!. TYPE (EPIT~ERMA[~ OR THERMAL) MATRIX: MATRIX DENSITY: MOLE CORRECTION (IN): TOOL STANDOFF (IN)~ 9302,0 bSND 41,00 g.?O 6 ~0 2,400 2,3!0 3,280 SANDSTONE 2,65 78,0 78.0 78,O RE~ARKS: TOOL STRING (MOT-TOP}: D!TE-$bTT-CNTM SGTL-TCCB-~M$ NEUTRON ~ATRIX : ~ANDSTO~E, HOLE CORR~ ION CT CNL RUN WOT~ A BOWSPRING, MAXIMUM DEVIATIO~ 35 0 AT: 51~! ~D. AFTER'bOG SONIC CHEC~I$~.S~ 'A~r E~D O~? ~i~IN PASS CNb' RUN IN' CASING ~ITH BbS (, .... CASE, ND B?X GEOL.}GIST ON LOCATION FOR WITNESSING LOGS, $ bis FORMAT DATA PAGE: I4 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYP~ - 64EM ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 192 4 66 5 66 6 73 7 65 8 6~ 0,5 9 65 VT IS TaDe Verification 5Istinq chlumberger Aiaska ComPutinq Center 2). -'SAY'-t992 06:32 PA~E~ 15 !! 66 5 12 68 13 66 0 !4 65 FT t5 66 68 16 66 ! O 66 I ** SET NA~E SERV UNIT ID mmM#mmmmmm##mmmmmm D~PT FT DT BH~ U$/F TT! BMR US TT2 BHR US TT~ BMR US TT4 BHR US SP BMR MV G~ BH~ GAPI TENS BHR bB MTE~ BHR DEGF M~E$ BHR OH~ HTEN BMR CIDP DTR ~MHO IDPH DTR OHMS CIMP DTR MMHO CILD DTR MMHO ILD DTR OHMS CIL~ DTR M~HO ILS DT~ OH~M IFRE DTR HZ IDOF DTR I~OF DTR IIRD DTR MMHD IIXD DTR IIRM DTR MMHO I X~ DTR M~HO SFLU DTR SD DTR MV GR DTR GAPI TENS DTR bB MTE~ DTR DEGF M~ES DTR OHMM HTEM DTR NPH! CNR PU RTN~ CNR TNPW CNR PU TNRA C~R SERVICE ORDER # 548255 548255 548255 548255 548255 548255 548255 548255 548255 548255 548255 54 255 54~255 548255 54~255 548255 548255 548255 548255 548255 548255 548255 548255 548255 548255 548255 548255 548255 548255 5~8255 548255 548255 548255 548255 548255 548255 548255 548255 API API APl API FIb~: NUMB NUMB SIZE 'REPR PROCESS LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) 00 000 00 0 4 ! ! 4 68 0000000000 00 000 00 0 4 I 1 4 68 0000000000 O0 OeO O0 0 4 I I 4 68 0000000000 O0 000 00 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 I i 4 68 0000000000 O0 000 O0 0 4 I I 4 68 0000000000 O0 000 O0 0 4 1 I 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 00 000 00 0 4 I ! 4 68 0000000000 00 000 00 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 I I 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 ! I 4 68 0000000000 O0 000 O0 0 4 ! I 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 ! 4 68 0000000000 O0 000 00 0 4 1 I 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 I 4 68 0000000000 O0 000 O0 0 4 I 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 b8 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 i 4 68 0000000000 00 000 00 0 4 1 1 4 68 0000000000 O0 000 O0 0 ~ 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 b8 0000000000 O0 OOO O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 I 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 I 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 IS Tape Verification Li. stina Cblumber[.~er AlasKa Compoting Center 21 ~:~AY-lg92 O6:32 PAGE: 16 SERV ONIT ....... I APl . APl FILE; N.JMB MUMS SIZE R OCES6 ID ORDER # LOG TYPE CbASS MOD NUMB SAMP EbEM CODE (HEX) MPOR CNR PU 548255 O0 000 O0 0 4 ! I 4 68 0000000000 RCNT CNR CPS 548255 O0 000 O0 0 4 ~ 1 4 68 0000000000 RCFT CNR CPS 548255 O0 000 06 0 4 ! ! 4 68 0000000000 CNTC CMR CPS 548255 O0 000 O0 0 4 I 1 4 68 0000000000 CFTC CN~ CPS 548255 O0 000 O0 0 4 1 I 4 68 0000000000 GR CNR GAPI 548255 O0 000 O0 0 4 1 I 4 68 0000000000 TENS CMR LB 548255 O0 000 O0 0 4 I 1 4 68 0000000000 MRES CNR OHM~ 548255 O0 000 O0 0 4 I 1 4 68 0000000000 MTE~ CNR DEGF 548255 O0 000 O0 0 4 ! I 4 68 0000000000 HTEN CNR bM 548255 O0 000 O0 0 4 I I 4 68 0000000000 ** DATA ** DEPT. 960~.500 DT.BHR 95.t88 TTi.BHR 589,000 TT2,BMR TT3,BHR 59~ 000 TT4 BHR 41;0,250 ~P,BHR -127,i00'0 GR,BHR TE[;S,BHR 5055 000 MTEM:BHR 17I'1.25 MRE~iB~R 0'889 HTEN"BHR C!DP'DTR 71 250 IDPH.DTR 14'0.31 CIMP,DTR 73'500 IMPH'DTR CILD.DTR 73 375 ILD~bTR 13'617 Ct'bM,OTR 75'!88 ILM.DTR IFRE.DTR 20.000 IDOF.DTR 3.000 I~OF,DTR ~2'000 IIRD,DTR IiXD.DTR 8,.14~ t!R~,DTR 71.313 ItX~,'DTR 14.922 SFLU.DTR MPE'S.DTR 0,889 MYEi~,DTR 81 00 NPHI:CNR 25::: 31 RTNR:CNR TMPM CMR 25'327 TNRA.CNR 21,~15 NPOR,CNR 25,327 RCNT CNR RCFT:CNR !051.993 CNTC'CNR 2716...38 CFTC;CNR !140,019 GR:CNR TMMS.C~ 5055,000 MRES,CbR 0,889 MTE~,CNR 171,125 MTEN.CNR DEPT 9500.000 DT,BHR 85.563 TTI:~HR 572.000 TT2.BHR TT3:BHR '570,000 TT4~BHR 391'000 SP ~R -147.875 GR.~R TENS.BMR 5090.000 MTEM.~HR 171 1.25 MRE$.BHR 0.889 HTEN.BHR CIDP,DTR 34.031 IDPH,DTR 29:375 CIMP.DTR 49'969 IMPH.DTR IFRE.~TR ~01000 IDQF,DT8 0'000 IM~F,DTR 0 O0 IIRD,DTR IIX~.DTR 5 395 XIR~,DTR 47,t~1 IIX~,DTR 111~22 SFbU,DTR SP.DTR -1871875 GR,DTR 19, 2 TEN$,DTR 5090,000 MTEM.DTR ~PE$ ~TR 0,889 HTEN,DTR 88~,500 MPHI,CNR 2~,2~ RTNR,CNR T~H:CNR 23,897 TMRA,CNR 2,355 N~OR,CNR 22,~48 RC~T.CNR RCMT,C~R 1145,672 CMTC,CNR 2'715,~3 CFTC,C~R 1186, 2 GR,C~R TM~S,CNR 5090,000 ~RE$,CNR O, 9 ~TE~,CNR 171,125 HT~N,CNR DEPT. 9294,500 D'r. BHR 56.668 TTI.BHR 383.000 TT2.BHR TI3.BHR 386.250 TT4 BHR 273.000 SP,~HR -110..563 GR BHR , ~ ','~ . -- · ' .. TENS.BHR 5045 000 ~-TE~ BHR 169.750 MRES.BHR 0 905 HTEN.BHR CIDP.DTR 60.625 IDPH.DTR i6.4~4 CIMP.DTR -335.000 IMPH.DTR CILD.DT~ 65.875 ILD.DTR 15.172 CILM.DTR -330.500 ILM.DTR IFRE DTR 20.000 IDQF DTR 0.000 X~QF.DTR 0.000 IIRD.DTR IIXD'DTR -448.500 IXR.~:DTR -322.500 IIXM.DTR 1207.000 SFLU.DTR SP~DTR -150.563 GR.DTR 35.875 TEN$.OTR 5045.000 MTE~.DTR MRES.DTR 0,905 HTEN.DTR ~027.000 NPHI.CNR 29.245 RTNR.CNR T~,DH.C[~R 30.995 TNRA.CMR 2.689 NPOR.CNR 29.466 RCNT.CNR 397,000 19'~72 819'000 13'594 1~:'289 65"875 20'484 171'~1215 2,566 2735;694 19'.t72 819.000 392,750 19.172 885,500 20.000 20.188 31.547 25 328 2 432 28271104 19 172 88515OO 270.750 35.875 1027.000 1950,000 1950,000 64.125 9696.000 169.750 2.696 1795.081 Tape verification List. in cbtumberger AlasKa ComPhtln~ Center 2!'MAY-1992 06:32 PAGE: t7 REFT CNR 573.497 C. !C,CNR T~3NS'CNR 5045,000 ~RES.CNR 1712o268 CFTC,CNR. 0,905 MTEN,CNR~ 62~.763 GR.CNR 16' o750 MTEN · 35,875 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .,004 SERviCE : FbIC YERSIDN : O01A07 DATE : 92/05./16 MAX REC SIZE : !0~4 FILE TYPE : LO L~ST FILE ****, FILE }lEADER **** FILE NA~E : EDIT ,005 SERVICE : FLOC VERSION : OO1A07 DATE : 92/05/t6 ~AX ~EC SIZE : !024 FILE TYPE : LO LAST FILE : FILE NUMBER 5 RA~ CASED HOLE ~AIN PASS Curves and log geader data for open hole logs run into casing, RUN NUMBER: 1 TOOL STRING NUMBER: 1 pASS NUMBER: 3 DEPTH !NCREMENT~ -,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTH 9426,0 LOG HEADER DATA mATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TI~E LOGGER ON BOTTOm: TD DRILLER (F~): TD LOGGER(FT). TOP LOG INTERVAL (FT}: BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR)~ STOP DEPTH 07-MAY-92 CP 32,6 1500 ~055 9945.0 9958.0 6900,0 9899,0 !800.0 07-~AY-92 07-MAY-92 iS Tape Verification Listing chlumberqer laska CoMPuting Center 2t-~AY-1992 06~32 PAGE: 18 TOOL STRING (TOP TO BOTTO~) VENDOR TOOL CODE TOOL TYPE T~bE TELemETRY CART.~![.GE GR GAMMA RAY sOURCE BHC BO.REHOLE SONIC CART, BHC BORgMOLE~$ONIC SOND~ DTE DUAL IND[]CT.IO.N CART, DTE DUAL INDUC~IO~;~ SO~DE $ BOREH~LE AND CASING DATA OPEN MOLE BIT SIZE DRILLERS CASING DEPT.H (FT): LOGGERS CASING DEPTH BOREMOLE CONDITIONS ~UD TYPE~ ~!]D DENSITY {LB/G}~ MUD VISCOSITY MUD RESIoTIVITY COHM~) AT TEMPERATURE . MUD AT MEASURE[) TEMPERATURE (MT): MI)D AT BOTTOM HOLE TEMPERATURE (B~.!T): ~UD FILTRATE AT MUD FILTRATE AT ~UD CAKE AT (MT): MUD CAKE AT NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): ~ATRI×: ~ATRIX DENSITY: HOLE CORRECTION (IN): TgOL STANDOFF (IN): A~ AA TCC-~ ~40 SGC-SA 40 SbC-U~ DIC 430 DIS 430 8,500 9295.0 9302.0 8.80 41'00 .9,70 6.30 17~,0 2,400 2,310 3,280 78,0 S~NDSTOME 2.65 ~E~ARKS: TOOL STRING (BOT-TOP): DITE-SLTT-CMTH-SGTL-TCCB'A~S NE[!TROt~ ~ATRIX : SANDSTO~E, HOLE CORRECTION = CNL RUN WOTH A BOWSPR!~4G, DITE RUN WITH i 4" TEFLON ~TANOOFFS, SONIC WITH 1,5" ~AXIEUM DEVIATISN 35'0 AT 5111 ~D, AF?ER LOG SONIC CHECK IS SEEN AT END OF ~AIN PASS, CNL RUN IN CASING WIT~ BHS = CASE. NO B~X GEOLOGIST ON LOCATIO~ FOR WITNESSING LOGS, $ bis FORMAT DATA 21-MAY-Iq92 06:32 PAGE; 19 ** DATA FORMAT ~PEC!FtCATION R~;C,.ED ** SET TYPE - 64'E8 ** TYPE REPR COPE VALUE ! 66 0 2 66 0 3 73 60 4 66 5 66 7 65 8 68 0.5 9 65 Ft 1! 66 1.7 12 68 1,3 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 mm~mm~mmmm~mmmmmmm~mmm~m~m ** SET TYPE NAME 8ERV UNIT SERVIC ID ORDER DEPT FT ~R CSG GAP! NPHI CS~ PU TNPH CSG pi] TNR~ CSG NPOR CSG pi] RCNT CSG CPS RCFT CSG CPS CNTC CSG CPS CFTC CSG CPS TENS CSG bB MRES CSG OHMM MT~ CSG DEGF HTEN CSG LB 548255 O0 DO0 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 548255 O0 000 O0 0 5 54R255 O0 000 O0 0 5 548255 00 000 O0 0 5 548255 O0 000 O0 0 5 CHAN ** ... E APl API APl API FILE NUMB NUMB SIZE REPR PROCESS # bOG TYPE CLASS MOD NUmB SAMP ELEM CODE (~EX) i 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 6~ 0000000000 1 1 4 68 0000000000 1 ! 4 e8 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 ** DATA ** DFPT. 9426.000 GR.CSG 93,000 TNP~ C~G 23 427 TNRA CSG 2 440 RCFT,CSG 892.37~ CNTC.CSG 2324:915 MRES.CSG 0,922 MTEM,CSG 167.750 NPHI,CSG 19,345 RTNR.CSG NPOR,CSG 23.427 RCNT CSG CFTC,CSG 967.042 T '~ ' ....~s:csr~ HT~'.-N,CSG 747.000 2,594 2341,136 3130.000 IS T e verification Listt chlU~erqer AlasKa ComPuEi~ Center 21-MAY-!992 06:32 PAGE: 2O DEPT. 8500 000 GR,CSG TNP~.CSG 59:5§6 TMRA.CSG RCFT,CSG 294'162 CNTC'C_SG M:[~ES ' CSG 0,974 !4TEE' CSG DEPT 8000. 000 GR, TNPH:CSG '49,483 Ti~Ra. CSG RCFT.CS.G 300,490 CNTC'CSG MRES.CSG i, 045 M'TEM,CSG DEPT. 7500.000 GR.CSG TNpH,CsG 51,772 TNR~,CSG RCFT,CSG 2~.4 162 CN'TC,CSG .~ .~'~7% . · .. . MI~E. .... CSG ! 090 MTEM.CSG DEPT, TNPM,CSG RCFT CSG MRES CSG 7000.000 GR,C G 49,457 TNRA,CSG 320.986 CNTC.,CSG 1 · 090 MTEM,CSG D.:..~PT, TMPM,CSG RCFT.CSG 6B 89,000 GR. CS(,; 46,720 TNRA,CSG 362,~57 CNTC,CSG !. 09.4 ~.TEM, CSG ** END OF DATA ** 64,500 NPHI,C$~ 4,324 NPOR,CSG 1402..!58 .CFTC,CSG !61,875 HTE~,CSG 6!.031 NPHI,CsG 4,280 NPOR..CSG !4~'499 CFTC CSG .ooo 64,8~3 NPH1.CSG 4 3 0 !463 153 CFTC.CSG 149 500 HTEN,CSG 56 469 4 208 1401 57 ! 43 87~ NPHI, CSG CFTC, CSG HTEN, CS O .104,188 NPHI,CSG 4. I1 NPOR,C~G 1375.~62 CFTC'CSG~ 138. 500 HTEN"CSG !50 ? 53,262 RTMR.CSG 47.465 RCNT~CSG 357'565 T£NS.CSG. .984,500 52'456 RTNR,CSG 55'465 RCNT'CSG 9]~ 66t:000 TE~$.CSG. 54,272. RTNR'CSG 5 '~0 TENS.CSG 36~,96~ RCNT,CSG 1024'000 51,::!4~ RTNR.CSG 5t,820 RCNT.CSG 10 ,000 49 376 RTNR,CSG 49 1694 RCNT,CSG 3~8 969 TENS,.CSG 1186 000 42,374 RTMR.CSG 46,068 RCNT'CSG 387'342 TENs'csG 1235..000 5045'000 4,600 I526'445 4785' 000 4' 560 408'153 59 O, 000 4.5 00 141 O, 155 4435'000 4,524 I3:79'469 4465,000 4375,000 **** FILE TRAILER **** FILE NA~E : EDIT ,005 SERVICE : FLIC VERSION : O0!A07 DATE : 92/05/16 ~AX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TmAILER **** SERVICE NAME : EDIT DATE : 92/05/16 ORI~!M : FblC TAPE NA~E : 92302 CONTINUATIOM # : 1 PREVIOUS TAPE l COMMENT : BP EXPLORATION,PRUDHOE BAY,E-]l,50-029-2226600 Tape Yeri.f,.,icatio~ L~{st~.nQ ChlUmberger AlasKa comPutin~ Ce,ret 21-~AY-Ig92 06:32 PAGE= 2! DaTE : 92/05/16 ORIGIN : FLIC REE[~ NAME : 92302 CONTINUATI0~ # : PRE¥IOUS REEL : COMMENT : BP EXPLORATION,PR[]DHOg BAY,~-31,50-029-2226600
