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
198-074
OF TFJ • \ �a� THE STATE Alaska Oil and Gas 4.4i • ���_ '� of A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 AVIpF ,.\ h Q, Main: 907.279.1433 A6,44* Fax: 907.276.7542 www.aogcc.alaska.gov July 27, 2016 Mr. David Kumar Production Manager Savant Alaska, LLC 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 RE: No-Flow Verification Sw��� 7 Badami B1-15 PTD 1980740 Dear Mr. Kumar: On July 23, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Badami Unit B1-15 located on the North Slope, Alaska. The well is operated by Savant Alaska, LLC (Savant). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Badami B1-15 prior to the test. The well performance was monitored for three hours with resulting gas flow rates up to 480 cubic feet per hour and no liquid flow to surface, passing the no-flow test. The well is authorized to produce without a subsurface safety valve based on the passing test results. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Badami B1-15 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. Please retain a copy of this letter at the Badami field office. Sincerely, James B. Regg Petroleum Inspectioin Supervisor cc: P. Brooks AOGCC Inspectors EM , f Ala ka MEMORANDUM M StaO U State o s Alaska Oil and Gas Conservation Commission TO: Jim Regg � ?/ DATE: July 23, 2016 �� P. I. Supervisor 11°7//g- FROM: 4 FROM: Chuck Scheve SUBJECT: No Flow Test Petroleum Inspector Badami B1-15 /ant - 198-074 Saturday, July 23, 2016: I traveled to the Badami field to witness verification of no-flow status on Well B-15. The well was open to atmosphere with all appropriate test equipment installed and no discernable flow noted. The well was shut in for 3 hours with only slight pressure build up on tubing. Upon opening the Well to atmosphere the pressure rapidly dissipated with a maximum flow rate of 480 scf/hr of gas and no fluid observed. SCANNED APR U 6 2017, The following table shows test details: Time (Time Pressures' Flow Rate Start) (psi) Gas - scf/hr Liquid - gal/hr Remarks 10:00 0/0/0 0 0 open to atmosphere - 10:30 0/0/0 - 0 0 shut in 11:30 7/0/0 - 0 0 shut in 12:30 9/0/0 0 0 shut in - 13:30 12/0/0 0 0 shut in 13:30 12/0/0 480 ' 0 open to atmosphere 13:35 0/0/0 - 0 0 open to atmosphere - 1 Pressures are T/IA/OA Summary: This well exhibited inability to flow to surface unassisted. Attachments: none 2016-0723 No-Flow Badami B1-15 cs.docx Page 1 of 1 pr • lam; (7)t-I � (2$074fii Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, July 07, 2016 1:44 PM 1\Q ( 711? To: 'David Kumar' Cc: Leland Tate; Conrad Perry; Foerster, Catherine P (DOA) Subject: RE: Badami: 31-15 Well Problem Badami B1-15 (15L1; 15L2) PTD 1980740 (1980750; 1980760) Request to operate B1-15 an additional 14 days (not later than 7/21/16) without a SSSV is approved. Provide the following: - Describe what studies have been done to assist in coping with the paraffin problems in 131-15 - Describe the prevention and inhibition efforts in the past and that are planned moving forward - Frequency of interventions or treatments to mitigate the paraffin issue The referenced no-flow test for this well—should one be performed—must not be influenced by plugging from paraffin. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.reggPalaska.gov. From: David Kumar [mailto:dkumar@glacieroil.com] Sent: Thursday, July 07, 2016 8:45 AM To: Regg, James B (DOA) Cc: Leland Tate; Conrad Perry Subject: Badami: B1-15 Well Problem ANNE® NOV 2 2 2016 Mr. Regg, We have been having some ongoing issues with paraffin on B1-15 which is preventing us from having the SSSV installed and functional. We are requesting the commission to provide an additional 14 days of relief for either reinstallation of the SSSV and testing it or an ability to demonstrate a No-Flow test. We were confident the BHP was severely depleted and suitable for a No-Flow test, however, the well was locked up with paraffin. It took us 3 days to pull the SSSV and another two weeks to clean out a —55' 100% paraffin plug. The pressure bomb data confirmed our thoughts with a BHP of 1,415 psi at 11,500'. However the SSSV control and balance lines were also plugged. We attempted to heat the well up by flowing the well for a short period 1 • • after the BHP bomb to July 3rd, but it wouldn't clear to install the SSSV. We attempted an internal no-flow without success due to procedural problems and then shut the well in. It has been 34 days without a SSSV, however, it was shut-in for most of that period, but we wanted to make you aware of the situation. Please let us know on how to proceed. The well is currently shut-in pending approval. Please refer to the timeline below Thanks and Regards David Kumar Production Manager Glacier Oil and Gas SAVANT C*0k Irl€tErteq I„„..Ac _. 601 W. 5th Avenue,Suite 310,Anchorage,AK 99501 907-433-3822 (Direct)! 907-903-4164(Mobile) 907-334-6745(Main) 1907-334-6735(Fax) Email:dkumar@glacieroil.com June 1, Paraffin Blockage in B1-15.Well shut-in 2016 June 4, SSSV Removed 2016 June 19, Well brought online 2016 June 22, Well shut in due to paraffin blockage in control and 2016 balance lines June 23, Well and control lines cleaned and restated 2016 June 26, Well shut in for pressure data for no flow and 2016 cleaning June 28, Well and control lines cleaned and restated 2016 Jul 3,2016 Well shut in due to blockage in control and paraffin lines July 4,2016 Attempted No Flow Test July 5,2016 Well shut in pending AOGCC approval 2 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2 p DATE: Monday,June 27,2016 P.I.Supervisor (,� l 7/S(it, SUBJECT: Mechanical Integrity Tests l HILCORP ALASKA LLC 1-05 FROM: Bob Noble DUCK IS UNIT MPI 1-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Crg,e ' NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-05 API Well Number 50-029-21605-00-00 Inspector Name: Bob Noble Permit Number: 186-106-0 Inspection Date: 6/20/2016 Insp Num: mitRCN160620160848 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill 1-05 ' Type Inj G TVD 9473 , Tubing 4723 • 4723 - 4740 - 4756 - 4756 • PTD 1861060 - Type Test SPT Test psi 2368 - IA 1359 4723 4705 - 4722 - 4708 • Interval REQVAR .#, # P/F P / OA 100 110 110 110 110 Notes: Bi Annual to max anticipated injection presssure as per AIO 1.009. ./ Monday,June 27,2016 Page 1 of 1 • 0 • 9 q >,h a �, Z t E V (1) Pg o: co) C4 p. o y G R a 6,, ai x m R V w d o 6. O ° O o w NN h y P4 - V44 .4...1 U s44 6. O N CA a' aq a C. (1) 0 N a a '11 O �° IF y V C L co CA 0.1 c• t3 L' i7 Oit E .--i V a tQ� fl. O o O 10 L a V1 is a CA 73' cj Q) t4 .. I�l CJ 0 �a0a o N ¢ foo :51.rz o aa 0 z al W H U ,—.1 C� c b" o O. © U 6, ,.r 0 `) G H U- D • a R a 4—i .4 H rn V1 A a -; v) o a M r •-.1 av . a a '., v Q k. Z c °" z 0 �1 a q N d 0 a z 3 e '° z a e . 9 N N. o o7 a> cocq = 0. zvo s e 7) , 0 c4 a v a o U e ;4 c o ca L I se. °' va o , Gi CC o tt d O^ .1-(1°c � ' . = 0 ?� ca o .14 cu �,� to c. m C/1 a0c CVJ wyET. - IU o U ,cn ah ca i °r E y .- CA L o N °' 0 a C. CA _ � a C�/ c �V L a WS v) c:7 9 — ¢ r---+ - 3 Q N ' o c_ CL) j2 0 «+ 0 U H U CD . b ovL °' A~o l ad CD \ C.CI) F U a at .O O o, a. - 00 ti CA A , vi G. o a ..r a)i C3. N a I V] * L o .� �x i A 8 N- : 4 zN NzQ Z y tix 0 L z z 3z � -o Co . • Pn /' ©074-eQ Regg, James B (DOA) From: Regg,James B (DOA) Sent: Monday, June 27, 2016 3:55 PM To: 'Daniel Clark' Cc: David Kumar Subject: RE: B1-15 SSSV Removal Badami B 1-15 (PTD 1980740) Please read 20 AAC 25.265(3). The SSSV must be "made operable not later than 14 days after the date that the well is returned to service and tested not later than 5 days after installation". Doesn't have anything to do with the duration of the workover. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Daniel Clark [mailto:Daniel.Clark@savantalaska.com] Sent: Monday, June 27, 2016 9:48 AM To: Regg, James B (DOA) Cc: David Kumar Subject: RE: B1-15 SSSV Removal % DEC 1 4 20163. Jim, The BBE is the ball valve closure type of SCSSSV which was set in the safety valve nipple in B1-15. Attached is a schematic of the BBE. Regards, Daniel Clark Lead Field Operations Supervisor/ Petroleum Engineer NS Office: 907.659.1 322 Cell: 907.978.4132 ALT: Art Hoffman SAVANT ALASKA 1 1110 • From: Regg, James B (DOA) [mailto:jim.regg(aalaska.gov] Sent: Monday, June 27, 2016 9:07 AM To: Daniel Clark Subject: RE: B1-15 SSSV Removal What is BBE? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@yalaska.gov. From: Daniel Clark [mailto:Daniel.Clark@savantalaska.com] Sent: Saturday, June 25, 2016 7:04 AM To: Regg, James B (DOA) Cc: Wayne Kuykendall; Steve Sage Subject: B1-15 SSSV Removal Jim, This email is to request approval to have the SSSV removed from well B1-15 for more than 14 days. B1-15 had its BBE removed for maintenance below the SSSV after the wellbore plugged off with paraffin. The work was not anticipated to take longer than the 14 day period but the paraffin bridge was harder and deeper than expected. We are continuing maintenance work and paraffin mitigation in the wellbore and the control and balance lines. We are also anticipating performing a no-flow test on this well when we receive our flow meter back from calibration. This may not be for a few weeks and at that time we will provide a formal request for witness. In the event that the maintenance on the well is complete before we have our flow meter back from calibration we will reinstall the BBE SSSV,test the SSSV within 5 days after placing it in service as well as provide the AOGCC with a 48 hr notice the for the opportunity to witness the test using the web notice form. Regards, Daniel Clark Lead Field Operations Supervisor/ Petroleum Engineer NS Office: 907.659.1322 Cell: 907.978.4132 ALT: Art Hoffman SAVANT ALASKA 2 BI-15 (PTD #1980740) Classified as Problem Well . All, Well 81-15 (PTD #1980740) has been found to have sustained casing pressure on the IA. The TIO pressures were 4300/2880/40 psi on 04/23/07, at which time an IA bleed failed. The plan forward for this well is as follows: 1. F: Load and kill tubing 2. S:SetTTP scANNED APR 3 02007 A wellbore schematic has been included for reference. «81-15.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: Bl-l5.pdf Content-Type: application/octet-stream Content-Encoding: base64 7h I tq¡ ..IPIIO (I5á }A"7.J P·~ 11 120 ' V\..V"'( I ps, ~p .; $0 PSI' ""-') 25.7 Po ,,- ~ 1 of 1 4/25/2007 10:25 AM te . . , MICROFILMED 7/30/02 DO NOT PLACE . ANY NEW MATERIAL UNDER THIS PAGE Saved as M:lweepie/microfilm_marker,doc Well Compliance Report File on Left side of folder 198-074-0 BADAMI UNIT MD 12580 TVD 10729 ion Date: Microfilm Roll / - Roll 2 / Bl-15 50- 029-22878-00 BP EXPLORATION (ALASK A \ rNlt~ '~/28/98 Completed Status: 1-OIL Current: S~OZED Name L COMBO GAS-MD L COMBO GAS-TVD L ENG LG-TVD Interval Sent Received T/C/D L'/'~pERRy~L'BL(C) 11450'i252'5 7~~"' OH i'/2~"l/q;~ H---1 ...... 8/~/;8 --- 8/6/98 ......... C~,,~"SPERRY t~ (C) 9800-107 5 .~ O 8/4/98 8/6/98 ir. SPERRY BL(C) 9800-10725 ~ OH 1 8/4/98 8/6/98 L MUD-TVD ~9793-10729 ~ OH 1 L NGP/DGR/EWR4-TVO 5~' 6305-10729 ~/'2,,(~/~' /~"'3~ OH L NPG/DG~EWR4-MD ~ 6459-12580 ~ OH L PORE PRES-TVD ~ SPERRY BL(C) 9800-10725 OH 1 L PROO-GASLIFT ~;'50-11410 q/qff~ CH 5 L PROD-SP~EM/ ~AL 11100-12100 ~ ~ CH 5 10/7/98 10/8/98 10/7/98 10/8/98 10/28/98 10/29/98 10/28/98 10/29/98 8/4/98 8/6/98 10/5/98 10/6/98 10/5/98 10/6/98 Oq'5 R SRVY RPT ~t~RY 11395.53-12580. OH 9/21/98 9/24/98 ~} , , Daily Well OpsT//(a/~ -- ~7' Are Dry Ditch Samples Required? yes~___.~ And Received?~ye~ Was the well cored? yes .~. Analysis Description Received?-- ~ Samp~ Comments: Tuesday, August 01, 2000 Page 1 of 1 RE: Notification of Tubing/Inner Annulus Commu-;~ .~.tion in B 1-15 PTD 198-074 Subject: RE: Notification of Tubing/Inner Annulus Communication in Bl-15 PTD 198-074 Date: Mon, 17 Apr 2000 17:31:17 +0100 From: "Dube, Anna T" <DubeAT~BP.com> To: "'Blair Wondzell'" <blair_wondzell~admin.state.ak.us> Blair, The pack off tests showed that the packing is not causing the communication between the tubing and inner annulus of Bl-15. We believe the communication is due to the orifice valve being stuck with paraffin. We would like to place the well back on production and trouble shoot. Please advise me if we are allowed to place the well back on production or how we go about obtaining approval to do so. Thank you, Anna From: Blair Wondzell [SMTP:blair wondzellSadmin.state.ak, us] -- Sent: Thursday, April 13, 2000 11:46 AM To: Dube, Anna T Subject: Re: Notification of Tubing/ Inner Annulus Communication in Bl-15 PTD 198-074 Anna, Thanks for the information. Please keep us posted. Thanks, Blair "Dube, Anna T" wrote: > Blair, > This is to notify you that Badami well Bl-15 (198-074) has communication > between the tubing and inner annulus. The well was recendly shut-in beca use > tubing temperature and rate were falling off and we had difficulty getting > the well to take gas lift. Tubing and inner annulus pressure read 3400 psi. > The annulus was bled down to approximate 2500 psi and it pressured back to > 3400 psi over night. The well is currently shut-in while I work to get a > slickline unit out to Badami. We will check the wellhead packing to make > sure it is tight. I will keep you informed of the status of the well and > our plans to work it over. > Please feel free to give me a call if you have any questions at 564-5230. > Thank you, > Anna > Badami Production > ENS Subsurface > *Tel: (907) 564-5230 > *Fax: (907) 564-5200 > *mailto:dubeatSbp. corn 1 of 1 4/17/00 8:55 AM Re: Notification of Tubing/Inner Annulus Commu-;,' ition in B 1-15 PTD 1984)74 Subject: Re: Notification of Tubing/Inner Annulus Communication in Bl-15 PTD 198-074 Date: Thu, 13 Apr 2000 11:46:00-0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Dube, Anna T" <DubeAT~BP.com> Thanks for the information. Please keep us posted. Thanks, Blair "Dube, Anna T" wrote: > Blair, > This is to notify you that Badami well Bl-15 (198-074) has communication > between the tubing and inner annulus. The well was recently shut-in because > tubing temperature and rate were falling off and we had difficulty getting > the well to take gas lift. Tubing and inner annulus pressure read 3400 psi. > The annulus was bled down to approximate 2500 psi and it pressured back to > 3400 psi over night. The well is currently shut-in while I work to get a > slickline unit out to Badami. We will check the wellhead packing to make > sure it is tight. I will keep you informed of the status of the well and > our plans to work it over. > Please feel free to give me a call if you have any questions at 564-5230. > Thank you, > Anna > Badami Production > ENS Subsurface > *Tel: (907) 564-5230 >*Fax: (907) 564-5200 > *mai!to:dubeat~bp. com Iofl 4/13/00 11:49 AM STATE OF ALASKA ALASKA.'IL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 E~Operation Shutdown []Stimulate I--] Pull Tubing []Alter Casing [] Repair Well []Other 5. Type [~]well: Development I--I Exploratory [] Stratigraphic I~Service 4. Location of well at surface 3855' NSL, 117' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 2832' NSL, 608' WEL, SEC. 5, T9N, R20E, UM At effective depth 3138' NSL, 353' WEL, SEC. 5, T9N, R20E, UM At total depth 3138' NSL, 353' WEL, SEC. 5, T9N, R20E, UM [] Plugging [] Perforate 6. Datum Elevation (DF or KB) KBE -- 53.8O' 7. Unit or Property Name Badami Unit 8. Well Number B1-15 9. Permit Number / ApprovaI No. 198-074 399-218 10. APl Number 50-029-22878-00 11. Field and Pool Badami 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12580 feet Plugs (measured) 10729 feet 12580 feet Junk(measured) 10729 feet Length Size 73' 20" 4454' 9-5~" 10610' 7" 2025' 4-1~" Cemented 260 sx Arcticset I (Approx) 2065 sx PF 'E', 385 sx Class 'G' 190 sx Class 'G' Uncemented Slotted Liner MD TVD 110' 110' 4489' 4487' 10643' 9231' 10555'-12580' 9162'-10729' Perforation depth: measured true vertical 4-1~"Slotted Section: 11400'-12578';12128'-12138', 12163'-12173', 12173'-12193', 12193'-12213' 9770'-10729', 10336'-10344', 10366'-10374', 10374'-10391', 10391'-10408' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10472' Packers and SSSV (type and measured depth) HES 'TNT' permanent packer at 10443'; HES 'X' SSSV Landing Nipple at 2204' 13. Stimulation or cement squeeze summary Add Perfs 11/11/99 - 11/12/99 RECEI¥.E Treatment description including volumes used and final pressure ~,~.L, ~ ~ ~9~ A~as~ Oil & Gas Cons. C~m'~s~)r, Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 338 Subsequent to operation: 513 5. Attachments 116. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Opercti.ops. I [] Oil [] Gas [] Suspended Service 7. I hereby certify that the/,fore,~o'~"g i)~ t~u,~tnd correct to the best of my knowledge Signed ! 0 Bill Turnbull I ~" Title Sr. Petroleum Engineer, ENS Prepared By Name/Number'. Form 10-404 Rev. 06/15/88 ~ Date I'~I' I~ ~ Anna Dube, 564-5230 "'.. ~' Submit In Duplica'te..O Summary of Perforation Wellwork on B:t-IS The perforation wellwork on multilateral Bl-15 was successfully completed November 11- 12. The job consisted of running three 23/4'' guns and perforating the 41/2"slotted liner in intervals 12,128-12,138 MD and 12,163 - 12,213 MD. Prior to the job, B1-15 was tested at 338 bopd with a gas lift rate of 1.4 mmscfd. The wellwork resulted in an exceptional increase in shut in well head pressure of approximately 4000 psi. The well was brought on line and the following well tests were obtained without gas lift: date oil rate gor 21-Nov-99 1754 2987 24-Nov-99 513 7026 25-Nov-99 477 6870 27-Nov-99 423 6516 RECEIVED 1999 Well Operations Report To: Anna Dube/Bill Turnbull From: Jeff Eckstein Date: November 11-12, 1999 Cost Code: BWEL00 Well' B1-15 Detail Code: Operation: Add perfs Job ID: Summary November 11, 1999: Made 2 gun runs, shot perforations, referencing the MWD MD final log. Gun 1 20' 12,193' to 12,213' Gun 2 20' 12,173' to 12,193' November 12, 1999: Made 1 gun run (used select fire for 2 different intervals) referencing the MWD MD final log. Gun 3a 10' 12,163' to 12,173' Gun 3b 10' 12,128' to 12,138' Perforation Charges: Atlas 2-3/4" guns, 6 spf, 60 degree phasing, "Predator" deep penetrating charges (15 grams). APl data: Total target penetration = 23.2" Entrance hole diamter = 0.28" Time Operation 0630 MIRU Atlas. WHP = 2400 psi, lAP = 3400 psi (bleed down), OAP = 0 psi. Troubleshoot problems with grease injection system. 1600 Finally got the grease injection problems sorted out. RIH with Gun 1 (20'). 1815 Make tie-in pass. 1830 Depth correction +76'. Log up into position. WHP = 2375 psi, lAP = 3450 psi, OAP = 0. 1850 ParkGun 1 at 12,190'. GRtoTS is3'. Shoot 12,193'to 12,213'. POOH. 2030 OOH with Gun 1 - all shots fired. 2100 RIH with Gun 2 (20'). 2305 Tie-in. Depth correction +79'. WHP = 2600 psi, lAP = 3550 psi, OAP = 0 psi. 2320 Log up into position. Park Gun 2 at 12,170'. GR to TS is 3'. Shoot 12,173' to 12,193'. POOH. 0050 OOH with Gun 2 - all shots fired. POP well - flow to 1s' sta~le separator. 0220 Shut-in well. WHP 2200 psi, lAP = 2100 psi, OAP = 0 psi. I~I.,~,~,~'L--! 0225 RIH with Gun 3a/b. 0445 Tie-in, log into position. WHP = 3500 psi, lAP = 2350 psi, OAP = 0 psi. 0455 Park Gun 3a at 12,147'. GR to TS is 16'. Shoot 12,163' to 12, 173'. 0458 RIH, log up into position. ~ _0i[&GasColls, C0~m~ 0508 Park at Gun 3b at 12,125'. GR to TS is 3'. Shoot 12,128' to 12,138'. POOH. 0730 OOH with Gun 3a/b - all shots fired. Rig down. 1020 WHP -- 3,600 psi, lAP = 3,60~0s~psi, OAP = 0 psi. 1030 Attempt to POP well B1-15. 1 sta~le separator flare valve went full open and would not close. SI all wells... Badami B1-15 Add perfs .... November 11 -12, 1999 '-~'~' Page 2 Fluids Pumped BBLS, Description 0 MeOH 0 2% KCL water 0 Diesel (Freeze Protect Prod Tbg) 0 Xylene 0 Total Fluids Pumped Oil & Gas Cons, Commissior~ Anchorage Well Test Plot WELL: Bi-15/BADAMI Dates from 09/08/1998 to 12/01/1999 10000 S n N n ,I F M A M I ,I A ~ "' ~:' IJ ,~ ,~1t_'~17 Q N m m , , , ':. :. :_:_ ~ :. :. :_ :_ :_,..~::_ :. :. :. :_ :. i :_ :. :. :_ :. :_ :.:. :. :. :_ :. :.: :. :. ! :_ ! !:! :_ :_ :. :_ :_ ::. :. :. :. :_:. :_::. :_:. :_ :. :. i :_ :. :. :. :. :.::. :_ :_:_ :. :_ ~~,.~.:~,*~L :_:! :. :.! :.~ .... : ..... ~'-x ...... ~ ............. : ...... : ...... :- ...... : ...... ~ ...... : ...... ! ...... n~l~ ! ...... ~--/--: ........... I .................................................................................. ~'-- ,:,- - i .... : ..... ~_ .:~ ..... : ............. : ...... : ...... ,: ...... : ...... ; ...... : ...... :_-~. .... :_ ~.~. ~..~--~ .... ,~.~ ;£~. L.../__ _: J, ..... :..~ .......... : ...... : ...... : ....... : ...... ~ ...... : ...... i .u.~. ~... J__ _%A__.: ...... : ' / '~ ..... " ' ' *' ' ' ' '~Jk: . ,, , ~. .... ,~ ,~ ~ ,¢ , , . /~ . ,,k' ! ! ! i : : : //: :: ~: :J.:':k:: Fli::: -~:: '-': :'::::: :~ :'::::: :' :-:< :4':::::: :':::::: ii -~i/: :l~i~: i/I: ~ iii:::::: ::::::: i:::::: ::: :/_,-,-: : i,: iF.': i i _X.i/- L~i i i }u i ~ i i,: i i i: i i/: i: 1:: i i i i i:i i i i i i t'%. - i i i i:i i i i i i: i~i i iq~-~ ~': i: .~W/' ...... : ........ illlliilYi' :A-* '"- .... ^J-:' '*- :% ;~k' ..... ,~/:~;*:/-~ '*': ' - ' :.:-~-,: :' :- :~ :-:: :-', .... :-:~::: ': -::: ::: :~ .... : ",-: .... ~ ...... : ....... ~%;:: ~::: :* :.:: :,: -,- x :~ ;,~,:. - :.::: :- :.:- :- :..- :... :.:~ :,j. :, .... ::::::::::::::::::::::::::::::::::::::::: ..................... .---!* ............... ...... ...... .--*,, ....... ::: :i::::: :;::::::;:: :: :~: ....... , ...... ....... ,:'~-'~* :::: :: ,:::::: :::::::: ~::: ::::::::::::::::::::::::: :<i .... '.. ...... ' ...... L ............. ' ...... ' ...... ' ....... ' ...... L ...... ' ...... .' ...... ' ...... .' ...... ' ....... , , , ~ , ~ , , , , , , , .... ,- ...... , ...... r ............. , ...... , ...... ,- ...... , ...... ,- ...... , ...... · ...... , ...... -, ...... , ....... , , , , , , , , , , , , , , , , , , , , , ~ , ~ , , , ~ , , , ~ , , ~ , ~ , ~ · ' __ ~' ~ ..... ' ............... ~. ' ' ' ' ' ' ~',~.~ li~ ~ i ~ ~ ~ ' .... .L_ _ '.. i i i i , i i i i i i i i'~'1 9000 8000 7000 6000 5000 4000 3000 2000 1000 900 800 7OO 600 500 400 3OO 2OO 100 9O 8O 7O 60 5O 4O 30 20 10 9 8 O N D J F M A M J J A $ O N 1998 1999 , ~ 60 ........................ , , , 60 ........................ , 40 ............................................................ -4~,D' ~ ......................... ' ...... 2o S O N D J F M A M J J A $ O N 1998 1999 December 01 1999 OPE V1.1.25 ~ Gross Fluid --e---- Oil Rate G.O.R. Gas Lift · Man. Pressure Man. Temp. Kelly bushing to wellhead/GL (fl) 35.3 Wellhead to sea level (ft) 19.1 B1-15 L1 B1-15 L2 B1-15 Conductor HES "X" Safety Valve Landing nipple Surface Casing Camco KBG2LS 4 1/2" x 1" GLM Camco KBG2LS 4 1/2" x 1" GLM Camco KBG2LS 4 1/2" x 1" GLM Camco KBG2LS 4 1/2" x 1" GLM Camco KBG2LS 4 1/2" x 1" GLM Camco KBG2LS 4 1/2" x 1" GLM HES "TNT" Permanent Packer HES "XN" Landing Nipple Wireline Entry Guide Top slotted Liner Hanger Intermediate Casing (ick-off point _~-3/4" 6 spf 60° phasing Slotted Liner Date Rev by IComments BP EXPLORATION Memorandum To' Blair Wondzell fm' Bill Turnbull December 1, 1999 Re' 10-404 for perforations on Badami B1-15 Blair, Please find attached the 10-404 report for your records for the perforating job on Badami Bi- 15 which occurred November 11-12. Included are a copy of the wellwork telex, a summary of the wellwork with well test information, a current plot of well test data, and an updated completion diagram. If you have any questions on the information provided, please feel free to give me a call. Regards, Bill T~rnt Senior~P~ roleum Engineer Eastern North Slope 564-4662 ORIGINAL BP EXPLORATION Memorandum To: Blair Wondzell fm: Bill Turnbull Re: November 2, 1999 10-403 for perforations on Badami B1-15 Blair, Please find attached the 10-403 application for your approval for a perforating job on Badami B:[-15 which we would like to carry out this weekend. If you have any questions regarding the program please give me a call. This perforating job is similar to the job we had planned Qn B1-28, but which is now currently delayed. Unfortunatel~-aue to fill in the hole, we were unable to perforate that well as planned. Regards, Senior troleum Engineer Eastern North Slope 564-4662 BP EXPLORATION Memorandum To: Blair Wondzell fm' Bill Turnbull Re' November 2, 1999 10-403 for perforations on Badami B1-15 Blair, Please find attached the 10-403 application for your approval for a perforating job on Badami B1-15 which we would like to carry out this weekend. If you have any questions regarding the program please give me a call. This perforating job is similar to the job we had planned on B1-28, but which is now currently delayed. Unfortunately due to fill in the hole, we were unable to perforate that well as planned. Regards, Bill Senior Engineer Eastern North Slope 564-4662 STATE OF ALASKA ALASKA"oiL AND GAS CONSERVATION CO'~MISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. I [~] Development KBE = 53.80' [] Exploratory 7. Unit or Property Name 3. Address []Stratigraphic Badami Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 J-~Service 4. Location of well at surface 3855' NSL, 117' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 2832' NSL, 608' WEL, SEC. 5, T9N, R20E, UM At effective depth 3138' NSL, 353' WEL, SEC. 5, T9N, R20E, UM At total depth 3138' NSL, 353' WEL, SEC. 5, T9N, R20E, UM 8. Well Number B1-15 9. Permit Number 98-074 10. APl Number 50-029-22878-00 11. Field and Pool Badami 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12580v'~-eet 10729V~feet 12580 feet 10729 feet Length Size 73' 20" 4454' 9-5/8" 10610' 7" 2025' 4-1/2" Plugs (measured) Junk (measured) Cemented 260 sx Arcticset I (Approx) 2065 sx PF 'E', 385 sx Class 'G' 190 sx Class 'G' Uncemented Slotted Liner ORIGINAL MD TVD 110' 110' 4489' 4487' 10643' 9231' 10555'-12580' 9162'-10729' Perforation depth: measured 4-1/2" Slotted Section: 11400'- 12578' true vertical 9770' - 10729' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10472' Packers and SSSV (type and measured depth) HES 'TNT' permanent packer at 10443' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation November 6, 1999 16. If proposal was verbally approved Name of approver contact Engineer Name/Number: Date approved Anna Dube, 564-5230 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Anna Dube, 564-5230 17. I hereby certify that the~oing~.~true and correct to the best of my knowledge Signed / ~'~ ~ ~ LJ--Je~Turnbull ~_~_..~ Title Sr. Petroleum Engineer, ENS Commission Use Only -- Date Conditions of Approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test Subsequent form requ~,~l~- ~o'4e e6 Approved by order of the Commission ORIGINAL SIGNED BY v,,*~, ~mmissioner Form 10-403 Rev. 06/15/88 Rub~, i, N. C,i,i~[en~on tAppr°val N°',..'¢ CF',~ / ¢ Date //~.00-' ¢ Submit In Triplicate BP EXPLORATION Memorandum To: J. Powers/M. Warren fm: A.Dube Re: Perforate: Well Bl-15 November 2, 1999 Well B 1-15 is a multilateral well completed with uncemented slotted liners across the reservoir intervals. The well never performed as well as predictions would have lead us to expect (see well test history). One of the possible masons for this under-performance is formation damage caused by the drilling or completion fluids. The purpose of this operation is to attempt to increase the production rate from the well by perforating past the possible damaged zone in the lateral in which we retain access. Please perforate the following intervals in B 1-15: 12128'-12138' MD 12163'-12213' MD Perforation should be with 2 3A" guns, 6 spf, 60/180° phasing, Predator deep penetrating charges. Depth control will need to be by perforating gamma ray if available. Any questions or comments may be directed to Anna Dube (x5230). Approved by Gary Osborne Date xc: B 1 - 15 Well File attachments: copy of reference log completion diagram well test history FINAL MD 1'600 / 1:240 MD Milo I FEWD SYSTEM I ROP RATE OF PENETRATION NGP NATURAL GAMMA pROBE DGR DUAL GAMMA RAY EWR4 ELECTROMAGNETIC WAVE RESISTIVITY I ~ i -~l [ Company ! ! i i ~,i [ Rig · NABORS 28E : o~ ..i ~, ~1 Field · BADAMI > , ~ , = I ~ I W=~47' 05:40.087 ~ ~ ~] ;:~ ~] ~l~ 3855FSE 117FEL S08 T ' ~ " ] ' ' ~ ' ' ' Permanent Datum ~ HSL Ele/.; O. Log Heas. F~om : RKB 53.B2 ~t ~ ~,] API Nu~e~ : ~ , Borehol, e Record : _ _ : BP EXPLORATION (ALASKA), INC. Y=5906425.04 ASP SOB TOgN R20E Elev.: 0.00 ft ft Ab.Perm. Dat. Job No: AK-VC-80259 OTHER SERVICES Dir. Drilling Mudlogging Elev7 KB 53.82 DF 52.32 GL 19.10 WD 0.00 Casing Record Weight From To (lb/£t) (ft MD) (ft MD) 47.0 0 4489 29.0 0 10644 : -- ". - .-_.- - -:.L? Kelly bushing to wellhead/GL (it) :35.3 Wellhead to sea level (fi[) 19:1 , B1-15 L1 B1-15 L2 B1-15 DateRev by Comments .#.###. M Sauve initial design - corrected 1o tubing tally Conductor 20.00019.12491.5 115.3 60.9 0.0 HES "X" Safety Valve Landing nipple 4.5 3.813 2204,9 2150.0 1.4 Sur[ace Casing 9.625 8.681 40 4487.0 4431.5 1.0 Camco KBG2LS 4 1/2" x 1" GLM 3039,7 2984.6 0.9 Camco KBG2LS 4 1/2" x 1" GLM 4047.7 3992.3 1.5 Camco KBG2LS 4 1/2' x 1' GLM 6308,6 6147.6 41.6 Camco KBG2LS 4 1/2" x 1 · GLM 9012.8 7956,3 44.0 Camco KBG2LS 4 1/2" x 1" GLM 10064.18730.8 40.2 Camco KBG2LS 4 1/2" x 1' GLM 10334.48937.5 40.2 HES"TNT" Permanent Packer 5.875 3.958 23-29 10442.69020.8 39.7 HES 'XN" Landing Nipple 4.5 3.725 10459.79034.0 39.6 Wireline Entry Guide 5.25 3.958 10472.19043.6 39.5 Top slotted Liner Hanger 7 10566.09116.6 38.9 Intermediate Casing 7.000 6.184 29 10643.09177.0 38.3 Kick-off point 11495.09776.6 47.6 Mid reservoir for GL design 12254.110389.531.5 Slotted Liner 4.500 3.958 12.6 12580.010875.626.8 Well Test Plot WELL. Bi-15/BADAMI Dates from 09/08/1998 to 11/01/1999 25 0 10000 9000 8000 7000 6000 5000 4000 3000 2000 lOOO 900 800 700 600 500 400 300 200 I F M A M I ,I A ,S Q lOO ..... : ..... ~r-1 ....... : .............. : ...... ! ...... ~ ...... ~ ...... ~ ...... ! ...... ~ ...... ~ ...... ! ....... ...... ', ..... 1' ",/ ....... ', ....... , ....... ', ...... ~ ...... ~ ...... ~ ...... ~ ...... ~ ...... ~ ...... ; ...... ~ ..... 4 "~ .... ' .... '~' "~ ...... ' .............. : ...... : ...... : ...... : ...... i ...... : ...... :' '; .... "'~' ~"~'"'~': , , , ~ .... ~ , ,~ , , , / ,, /, ,~ ,, ~./: ~- ~ ...', ', ', I',/ / / ~ ',~ ',/ ', ', : ,/ , , , '\ , , ..~.... , , I, '[ , ,~ , , , :~:: ~: k::X::: ¥:-~:: :::: :':::::: ~ ~:::::::: i:-~ -:..: L.: .-'__.:::: ~::::: :~i ~,:/:: ~ !,t~: ~ ~:::::: !:::::: i!:: :..:: ! ',~i--,~ -,, .......~,, ..... ~, -..;~-~-,¢ -/ ..... ,, ...... ,-, ...... ,, ...... . ...,:' , ............... .... : ......... ,; ,i.:.' ..................... ,- '~',' -.-.'.-.~ ...... i ...... ~:' ' :"', :' ~:,:: :::::: :.~::: .~: :~ :~::;::::: :~/:~.~/~ :,::::: =================================:::::::::::::::::::::::::: · % ........ '~ ...... ~--~ ..... '~-®¢-~' ~-z '~/- -\~ .... -~ ................. ¢:..~-z -¢ ...... -¢~ · ..~- ¢ .... x ................ · -~? ...................... ~ ...... ~- V'~' ~";--"' .................... ~*e¢ -, v ...... ¢ ...... ' -~- - -¢¢'¢-~- ~ - *- '~ ...... , ...... ' ....... ' ....... ' .............. ' ...... L ...... ' ...... L ...... ' ...... L ...... ' ...... 2 ...... ' ...... ., , , , , , , , , ~ , , , ..... , ....... , ....... , .............. , ...... ~ ...... , ...... ~ ...... , ...... ~ ...... , ...... ~ ...... , , , ~ , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , ~ , , , , 90 80 70 60 50 40 30 20 10 9 S O N D J F M A M J J A $ O' 1998 1999 120 100 80 60 40 2O 0 ,7:" ': ..... _.-;- - ;':'_-_' i,': ~'o S O N D 1998 ........................................ ~ ...... ., .................... ' ' "~"~'~"~"~"'~' '~ '~'""~'"~ ~ '~ -' ~'~-'~"~-' 0 '~-'~O ' 0~"~-'00 ~ ', J F M A M J J A S O 1999 November 01 1999 CPE V1.1.25 Gross Fluid Oil Rate G.O.R. Gas L ft · Man. Pressure Man. Temp. Choke WC Def/Meas. BP EXPLORATION, Alaska Date: 10-28-98 Transit 89762 BADAMI OPEN HOLE LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Rec Date Rec Company Comments Type Code B1-15 22-Jul-98 OH SPERRY MWD, MD, ROP, NGP, DGR, EWR4, WITH DIR DRILLING, MUDLOGGING B1-15 22-Jul-98 OH SPERRY MWD, ']'VD, NGP, DGR, EWR4, WITH DIR DRILLING, MUDLOGGING B1-15L1 05-Jul-98 OH SPERRY MWD, MD, ROP,NGP, DGR, EWR4, WITH DIR DRILLING, MUDLOGGING B1-15L1 05-Jul-98! OH SPERRY MWD, 'I'VD, NGP, DGR, EWR4, WITH DIR DRILLING, MUDLOGGING B1-151_2 15-Jul-98 OH SPERRY MWD, TVD, NGP, DGR, EWR4, WITH DIR DRILLING, MUDLOGGING B1-15L2 15-Jul-98 OH SPERRY MWD, MD, ROP, NGP, DGR, EWR4, WITH DIR DRILLING, MUDLOGGING Please sign and return one copy of this transmittal to: Carla H. Mclntosh Petrotechnical Data Center LOG DATA OOlblueline/1 RS A- 1 blueline/1 RS DNR-1 blueline BP - - 1 blueline BP--1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd Evelyn Raybon Ken Lemley RECEIVED OCT ?_ ~ 1998 Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 10-7-98 Trans# 89596 BADAMI OPEN HOLE LOG DATA q~ ,o7~o q~3. Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Trans Num Sw Name iLog Type Rec Date Company Code Run Num Api Num 89596 B1-15L1 MUDLOG 02-Jul-98 SPERRY I 500292287860 89596 B1-15L2 ~MUDLOG 15-Jul-98 SPERRY I 500292287861 89596 B1-15L1 MUDLOG 04-Jul-98 SPERRY I 500292287860 89596 B1-15L2 MUDLOG 15-Jul-98 SPERRY 1 500292287861 89596 B1-15 MUDLOG 20-Jul-98 SPERRY 1 500292287800 89596 B1-15 !MUDLOG 20-Jul-98 SPERRY 1 500292287800 Please sign and return one copy of this transmittal to: Carla Harris Petrotechnical Data Center -. LOG DATA AOGCC - 1 blueline/1 sepia Howard Oakland PETROFINA - 1 blueline/1 sepia Mike Engle DNR - 1 blueline Tim Rhyherd BP - - 1 blueline Evelyn Raybon OCT 0 7 !998 O~l & Gas ~ns. ~om~ Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 10-5-98 Trans# 89627 BADAMI CASED HOLE LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Trans Num Sw Name Log Type Rec Date Company Code Run Num Api Num 896271 B1-15 SPINNERFFEMP 09-Sep-98 ATLAS 1 500292287800 89627~ B1-14 PFC 14-Sep-98 ATLAS I 500292287400 89627~ B1-16 PFC 15-Sep-98 !ATLAS 1 500292288000 89627' B1-16 PFC 04-Sep-98 ATLAS 1 500292288000 89627 B1-21 SPINNER/TEMP 09-Sep-98'ATLAS 1 500292280900 89627 B1-15 GAS LIFT SURVEY 09-Sep-98 ATLAS 1 500292287800 89627 B1-21 PFC 05-Sep-98 ATLAS 1 500292280900 Uti ~89627 B1-11 PRODUCTION LOG 13-Sep-98 ATLAS 1 500292282900 Please sign and return one copy of this transmittal to: Carla Harris Petrotechnical Data Center LOG DATA AOGCC- 1 blueline/1 sepia PETROFINA 1 blueline/1 sepia DNR - 1 blueline BP - - 1 blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh OCT O 6 19'98 0ii-;:~ Gas Cans Commi~ior~ Anchorao? Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: Trans# 08-04-98 89380 BADAMI LOG DATA & DISKS Enclosed is the materials listed below. If You have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Jog Type Rec Date Log Version Comments 1' B1-15 ~' MUDLOG 21-Jul-98 TVD PORE PRESSURE VS MUD WEIGHT B1-15 ~MUDLOGi 21-Jul-98 TVD ENGINEERING LOG B1-15 "MUDLOG 21-Jul-98 TVD COMBINATION GAS LOG B1-15 ,"MUDLOG 21-Jul-98 FIN COMBINATION GAS LOG ~ B1-15L1 ~UDLOGI 15-Jul-98 FIN PORE PRESSURE VS MUD WEIGHT B1-15L1 ~IUDLOGI 02-Jul-98 TVD COMBINATION GAS LOG B1-15L1 '~UDLOG 04-Jul-98 FIN ENGINEERING LOG B1-15L1 ,~IUDLOG 04-Jul-98 FIN COMBINATION GAS LOG ' ~1-15L1 VMUDLOG 15-Jul-98 TVD PORE PRESSURE VS MUD WEIGHT D B1-15L2"' MUDLOG 15-Jul-98 TVD COMBINATION GAS LOG B1-15L2 '~IUDLOG 15-Jul-98 FIN COMBINATION GAS LOG B1-15L2 'I~IUDLOG 15-Jul-98 FIN ENGINEERING LOG Please sign and retum one copy of this transmittal to: Nadene Reichert Petrotechnical Data Center Howard Oakland REC ,VED LOG DATA AOGCC- 1 disk/1 blueline~l sepia PETROFINA- 1 disk/1 bluelineJl sepia DNR - 1 disk/1 blueline BP -- 1 blueline BP --1 correlation log blueline Mike Engle Tim Rhyherd Jill Kanosh Ken Lemley AUG 0 6 i998 0i~ & Gss Cons. Petrotechnical Data-Center, MB3-3 g00 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hole #3 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-074 398-160 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22878-00 4. Location of well at surface · ! ~ 9. Unit or Lease Name ~ Badami Unit At top of productive interval ~,, ....... ~'~ ~ 10. Well Number ' B1-15 2832 NSL, 608' WEL, SEC. 5, TDN, R20E, UM i .~'i~-~-~ , ' ! ~ 11 Field and Pool At total depth~ .............. . 3138' NSL, 353' WEL, SEC. 5, T9N, R20E, UM ':-,~ ''r¢'~-'-~ ............ ~___. Badami 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 53.80'I ADL 367011 12. Date Spudded6/14/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Abandl15' Water depth' if °fish°re I 16' N°' °f C°mpleti°ns7/21/98 07/28/98 N/A MSL, One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12580 10729 FTI 12580 10729 FTI [~Yes E~NoI 2204' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run LWD/MWD, CDL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 37' 110' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40fl L-80 35' 4489' 12-1/4" 2065 sx PF 'E', 385 sx Class 'G' 7" 29fl Pl10 33' 10643' 8-1/2" 190 sx Class 'G' 4-1/2" 12.6# L-80 10555' 12580' 6" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 10472' 10443' MD TVD MD TVD 11400' - 12578' 9770' - 10729' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 140 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) AuDust 24, 1998I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL iCHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Badami Sands F5T 11812' 10074' Base Badami Sands QSB 12480' 10640' 31. List of Attachments Summary of Daily Drilling Reports, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge SignedMike E. Millle~~ ~~/ Title Badami Drillin9 Team Leader Date B1-15 98-074 398-160 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL,: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5'. Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility Badami CPF Well B 1-15 Page 7 Rig Nabors 28E Date 24 September 98 Date/Time 14 Jul 98 15 Jul 98 16 Jul 98 10:30-06:00 19-1/2 hr 17 Jul 98 06:00-17:00 11 hr 17:00-18:00 1 hr 18:00-18:45 3/4 hr 18:45-19:00 1/4 hr 19:00-00:00 5 hr 18 Jul 98 00:00-01:00 1 hr 01:00-02:00 1 hr 02:00-06:00 4 hr 06:00-06:30 1/2 hr 06:30-07:30 1 hr 07:30-06:00 22-1/2 hr 19 Jul 98 06:00-14:30 8-1/2 hr 14:30-15:30 1 hr 15:30-16:30 1 hr 16:30-17:00 1/2hr 17:00-22:15 5-1/4 hr 22:15-23:00 3/4 hr 23:00-23:30 1/2 hr 23:30-01:45 2-1/4 hr 20 Jul 98 01:45-05:45 4hr 05:45-06:00 1/4 hr 06:00-08:00 2 hr 08:00-06:00 22 hr 21 Jul 98 06:00-13:45 7-3/4 hr 13:45-16:00 2-1/4 hr 16:00-17:30 1-1/2 hr 17:30-19:00 1-1/2 hr 19:00-20:45 1-3/4 hr 20:45-01:15 4-1/2 hr Duration Activity 20:45-23:00 'X, 2-1/4hr R.I.H. to 10980.4~ 23:00-23:30 x,d,,/2 hr "xT~ok MWD surveS~4,10980.0 ft 23:30-00:15 374,~r R.l~.to 11685.0ft ~ ~15-02:00 1-3/~ Took ~ su~ey at 120~0 ~ 02:~6:00 4 ~ ~ Drilled to~36.0 ff ~ 06:00-~0 18-1/2 ~ ~ Drilled to 12~0 fl ~ ~ ~ RaPider ~o 504~(4-1/2in OD) l~~~ip~m smn~ ~2600.0 ~ ith 2500.0 . 21~5xx 1 ~ ~ SPliced B~k hne ~:15-02:30 ~-1/4 ~ ~ Pulled Dfillpi~n stands to 0.0 ~ 02~ P~e~~wivel ~ 03:30~:00 1/2 ~ ~ Installed Bore protect 04:00-0~0 2 ~ ~ ~ade up B~ no. 14 06:00-10:30 4-1/2 ~ DrilledR'I'H' to 11450.0 ~to 11472.0 ~ ~ ~ ~;'~f Drilled to 11495.0 fl ~ J - Circulated at 11495.0 ft Pulled out of hole to 10654.0 ft Flow check Pulled out of hole to 640.0 ft Pulled BHA Made up BHA no. 15 R.I.H. to 10620.0 ft R.I.H. to 11442.0 ft Set tool face Drilled to 11720.0 ft Drilled to 11808.0 ft Circulated at 11808.0 ft Pulled out of hole to 10654.0 ft Flow check Pulled out of hole to 1094.0 ft Pulled BHA Removed Wear bushing Made up BHA no. 16 R.I.H. to 11456.0 ft Took MWD survey at 11495.0 ft Took MWD survey at 11808.0 ft Drilled to 12375.0 ft Drilled to 12580.0 ft ~ '~'-D ~l- IFD Circulated at 12580.0 ft Pulled out of hole to 10654.0 ft R.I.H. to 12580.0 ft Circulated at 12580.0 ft Circulated at 12580.0 ft Progress Report Facility Badami CPF Well B 1-15 Page 8 Rig Nabors 28E Date 24 September 98 Date/Time 22 Jul 98 01:15-01:45 01:45-03:15 03:15-06:00 06:00-09:00 09:00-10:00 10:00-12:15 12:15-13:00 13:00-13:15 13:15-15:30 15:30-16:00 16:00-22:45 22:45-00:45 23 Jul 98 00:45-01:00 01:00-06:00 06:00-13:30 13:30-14:15 14:15-17:45 17:45-18:00 18:00-18:45 18:45-19:00 19:00-19:45 19:45-06:00 24 Jul 98 06:00-07:15 07:15-08:00 08:00-13:30 13:30-14:30 14:30-15:30 15:30-17:30 17:30-20:45 20:45-06:00 25 Jul 98 06:00-10:00 10:00-10:30 10:30-12:30 12:30-13:15 13:15-14:00 14:00-20:00 20:00-00:00 26 Jul 98 00:00-01:30 01:30-02:00 02:00-05:00 05:00-06:00 06:00-06:15 06:15-09:15 09:15-10:30 10:30-11:30 11:30-13:00 13:00-13:30 13:30-14:00 14:00-16:00 16:00-18:00 18:00-21:45 21:45-22:00 22:00-00:45 27 Jul 98 00:45-01:15 Duration 1/2 hr 1-1/2 hr 2-3/4 hr 3hr lhr 2-1/4 hr 3/4 hr 1/4hr 2-1/4 hr 1/2 hr 6-3/4 hr 2hr 1/4 hr 5hr 7-1/2 hr 3/4 hr 3-1/2 hr 1/4 hr 3/4 hr 1/4 hr 3/4 hr 10-1/4 hr 1-1/4 hr 3/4 hr 5-1/2 hr lhr lhr 2hr 3-1/4 hr 9-1/4 hr 4hr 1/2hr 2hr 3/4 hr 3/4 hr 6hr 4hr 1-1/2 hr 1/2 hr 3hr lhr 1/4 hr 3hr 1-1/4 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 2hr 2hr 3-3/4 hr 1/4hr 2-3/4 hr 1/2 hr Activity Circulated at 12580.0 ft Pulled out of hole to 10654.0 ft Pulled out of hole to 7000.0 ft Pulled out of hole to 658.0 ft (cont...) Serviced Block line Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 1986.0 ft (4-1/2in OD) Installed Liner hanger Ran Drillpipe in stands to 12580.0 ft Functioned Liner hanger Flow check Laid down Drillpipe of 3089.0 ft Laid down 9910.0 ft of Drillpipe (cont...) Rigged down sub-surface equipment - Liner hanger Laid down 1785.0 ft of Drillpipe Removed Wear bushing Installed Casing handling equipment Held safety meeting Serviced Production packer Ran Tubing to 4-1/2in (7100.0 ft OD) Ran Tubing to 8268.0 ft (4-1/2in OD) (cont...) Installed SCSSSV nipple assembly Ran Tubing to 10441.0 ft (4-1/2in OD) Monitor wellbore pressures Monitor wellbore pressures Monitor wellbore pressures Monitor wellbore pressures Circulated closed in well at 10310.0 ft Circulated closed in well at 10310.0 ft (cont...) Flow check Installed Tubing hanger Serviced Tubing hanger Held safety meeting Removed BOP stack Installed Xmas tree Removed Hanger plug Held safety meeting Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Installed Hanger plug Rig waited: Orders Retrieved Hanger plug Rigged up Chicksan lines Tested Side pocket valve - Via string Removed Xmas tree Rigged up Xmas tree Held safety meeting Circulated at 10472.0 ft Cleared Chicksan lines Progress Report Facility Badami CPF Well B 1-15 Page 9 Rig Nabors 28E Date 24 September 98 Date/Time 28 Jul 98 01:15-01:30 01:30-03:15 03:15-04:45 04:45-06:00 06:00-07:00 07:00-09:15 09:15-12:00 12:00-13:00 13:00-14:00 14:00-15:30 15:30-16:00 16:00-19:15 19:15-20:30 20:30-21:15 21:15-22:00 22:00-22:30 22:30-23:30 23:30-01:00 01:00-02:30 02:30-03:00 03:00-03:15 03:15-06:00 06:00-08:00 08:00-08:15 08:15-09:30 09:30-11:00 11:00-12:00 12:00-13:00 13:00-14:30 14:30-16:00 16:00-16:30 16:30-17:00 17:00-18:30 18:30-21:00 Duration 1/4 hr 1-3/4 hr 1-1/2 hr 1-1/4 hr lhr 2-1/4 hr 2-3/4 hr lhr lhr 1-1/2 hr 1/2 hr 3-1/4 hr 1-1/4 hr 3/4 hr 3/4 hr 1/2 hr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 2-3/4 hr 2hr 1/4 hr 1-1/4 hr 1-1/2 hr lhr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr Activity Held safety meeting Installed Slickline unit Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run (cra Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Rigged down Wireline units Installed High pressure lines Held safety meeting Tested High pressure lines Functioned Permanent packer Tested Tubing Tested Permanent packer Installed Slickline unit Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Rigged down Slickline unit Held safety meeting Circulated at 10334.0 ft Circulated at 10334.0 ft (cont...) Held safety meeting Freeze protect well - 140.000 bbl of Diesel Reverse circulated at 2200.0 ft Cleared Chicksan lines Installed Slickline unit Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Rigged down Slickline unit Installed Hanger plug Retrieved Xmas tree Installed Xmas tree rt...) CONFIDENTIAL RECEIVED AUG {2 1998 BPXA PDC Badami Alaska State Plane Zone 3 Badami CPF B1-~5 CONFIDENTIAl_ SURVEY REPORT ORI61NAL 5 August, 1998 Your Ref: API-500292287800 Last Survey Date 21.July-98 Job# AKVCS0259 KBE 53.80' DRILLING SERVICE"-' A DIVI~ION olr D~ INDU~ ~c. Survey Ref: svy477 Sperry-Sun Drilling Services Survey Report for BI-15 Your Ref: API-500292287800 Badami Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 11395.53 51.670 353.600 9713.68 9767.50 3996.27 N 553.52 W 5910430.61 N 363413.95 E 3140.39 11457.00 53.270 353.630 9751.12 9804.94 4044.72 N 558.94 W 5910479.15 N 363409.40 E 2.603 3179.12 11473.65 47.900 354.020 9761.69 9815.51 4057.50 N 560.32 W 5910491.95 N 363408.25 E 32.303 3189.37 11507.02 43.940 358.940 9784.91 9838.73 4081.41 N 561.83 W 5910515.88 N 363407.17 E 15.900 3209.08 11538.35 43.280 4.750 9807.60 9861.42 4102.99 N 561.14 W 5910537.45 N 363408.25 E 12.960 3227.94 11569.89 43.300 11.320 9830.57 9884.39 4124.38 N 558.12 W 5910558,78 N 363411.65 E 14.279 3247.83 11601.59 42.770 17.460 9853.75 9907.57 4145.31 N 552.76 W 5910579.61 N 363417.39 E 13.320 3268.53 11633.42 41.010 21.630 9877.45 9931.27 4165.33 N 545.66 W 5910599.51 N 363424.84 E 10.346 3289.35 11664.50 39.760 24.580 9901.12 9954.94 4183.85 N 537.77 W 5910617.88 N 363433.07 E 7.347 3309.29 11695.76 37.790 26.890 9925.50 9979.32 4201.49 N 529.28 W 5910635.36 N 363441.88 E 7,818 3328.78 11727.39 35.680 32.240 9950.85 10004.67 4217.94 N 519.97 W 5910651.64 N 363451.48 E 12.113 3347.68 11756.78 35.400 37.440 9974.77 10028.59 4231.95 N 510.22 W 5910665.48 N 363461,48 E 10.326 3364.71 11823.05 35.340 37.600 10028.81 10082.63 4262.38 N 486.86 W 5910695.48 N 363485.38 E 0.167 3402.82 11915.96 34.350 38.740 10105.06 10158.88 4304.11 N 454,06 W 5910736.62 N 363518.93 E 1.275 3455.49 12010.37 33.430 39.510 10183.43 10237.25 4344.95 N 420.84 W 5910776.85 N 363552.87 E 1.075 3507.60 12105.07 32.760 40.110 10262.77 10316,59 4384.68 N 387.74 W 5910815.98 N 363586.68 E 0.788 3558.70 12199.75 31.550 40.320 10342.92 10396.74 4423.16 N 355.21 W 5910853.86 N 363619.90 E 1.283 3608.44 12293.88 30.440 40.680 10423.61 10477.43 4460.02 N 323.73 W 5910890.15 N 363652.04 E 1.196 3656.25 12388.85 29.080 39.700 10506.05 10559.87 4496.02 N 293.30 W 5910925.60 N 363683.10 E 1.521 3702.78 12482.97 27.320 40.300 10589.00 10642.82 4530.09 N 264.72 W 5910959.16 N 363712.29 E 1.894 3746.71 12513.34 26.790 40.750 10616.04 10669.86 4540.59 N 255.74 W 5910969.50 N 363721.46 E 1.871 3760.33 12580.00 26.790 40.750 10675.55 10729.37 4563.35 N 236.13 W 5910991.90 N 363741.47 E 0;000 3789.94 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 31.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12580.00ft., The Bottom Hole Displacement is 4569.46ft., in the Direction of 357.038° (True). Comment Tie-on Survey Window Point Projected Survey Alaska State Plane Zone 3 Badami CPF Continued... 5 August, 1998 - 12:12 -2- DrillQuest Badami Sperry-Sun Drilling Services Survey Report for BI-15 Your Ref: API.500292287800 Alaska State Plane Zone 3 Badami CPF Comments Measured Depth fit) 11395.53 11457.00 12580.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9767.50 3996.27 N 553.52 W 9804.94 4044.72 N 558.94 W 10729.37 4563.35 N 236.13 W Comment Tie-on Survey Window Point Projected Survey 5 August, 1998 - 12:12 - 3 - DriilQuest red rvices rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 Date: To: From: June 23, 1998 Blair Wondzell Mike E. Miller Subject: Request For Sundry Approval Changes to Badami B1-15 Multi-Lateral Well Permit number 98-074 0ii & Gas (;.'0ns, O0mmissio~ The attached sundry requests the following changes summarized below to the Badami B1-15 Drilling Permit. 98-074 7" 29# USS95 7" 29# P110 7" casing grade was changed to P110 B1-15 Intermediate casing change grade of to provide consistency with APl. casing 98-074 7" intermediate casing set 7" at 10689' md, Original permit allowed casing set B1-15 setting depth: 11200' md, 9228' tvd below first sand to isolate the lost 9601' tvd circulation potential in that sand when weighting up for deeper sands. · ~r ~' .'r" ii~'~ ~...'r ~'~ ::~" ;:~ ': ~i; ~ ~;~ Optimization has indicated it is advantageous to set casing 100' tvd ,,., ¢, ,o¢~r~ above shallowest sand to avoid well , L. ;,! ,.,_-: z! ~-"~' '~¢':::' control and stuck pipe potential. The · ~,',*',"~; uh*'" ,'-.', ~' (~,as ,,~,,- ..... ,;,. (~;o?r;~:~isst0;:, lost circulation risk is mitigated by ~,-~,~,.'.",,~, better hydraulics and understanding of ........... ¢~ formation strengths. 98-074 All three reservoir Do not displace to Core studies recently completed B1-15 penetrations were to be OBM. indicate leaving a high-viscosity water displaced to Oil Based based mud will result in lowest Mud for formation damage formation damage. protection 98-074 Tubing to be run to 11100' Run tubing to 10539' By setting the 7" casing higher above B1-15 md. md / 9046' tvd. the shallow sand, the tubing must move Primary up accordingly - to be set 100' above wellbore top of liner hanger. Hanger to be set 50' inside 7" shoe. 98-074 MWD and wireline logs MWD logs only Running additional wireline logs on first B1-15 penetration - may provide guidance on placement of subsequent penetrations, and improve drilling optimization. 98-074 391' of slotted liner 2002' of slotted liner This full slotted liner allows future re- B1-15 from TD to 50' md entry assurance into primary wellbore. inside 7" casing. STATE OF ALASKA ALASKA bye- AND GAS CONSERVATION coMI~flSSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: i~Abandon [] Suspend [] Plugging F-iTime Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3855' NSL, 117' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 2239' SNL, 488' WEL, SEC. 5, T9N, R20E, UM At effective depth N/A At total depth 2129' SNL, 312' WEL, SEC. 5, T9N, R20E, UM 12. Present well condition summary Total depth: measured 7601 feet true vertical 7061' feet Effective depth: measured 7601 feet true vertical 7061' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 80' 20" 4454' 9-5/8" Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A (Planned) (Planned) Type of well: [] Development I--] Exploratory [-] Stratigraphic Fq Service 6. Datum Elevation (DF or KB) Plan KBE = 54.4' 7. Unit or Property Name Badami Unit 8. Well Number B1-15 9. Permit Number 98-074 10. APl Number 50-029-22878-00 11. Field and Pool Badami Plugs (measured) Junk (measured) Cemented 260 sx Arcticset I (Approx) 2064 sx PF 'E', 371 sx Class 'G' MD 110' 4489' TVD 110' 4487' ORIGINAL 13. Attachments [] Description summary of proposal I-] Detailed operations program I--I BOP sketch 14. Estimated date for commencing operation June 29, 1998 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Mike Miller, 564-5066 Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Carol Withey, 564-4114 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed p 20~_._~ Mike E. Milller Title Badami Drilling Team Leader Commission Use Only Conditions of Approval: Notify Commission so representative may witness I Approva, No. Z~'/~'~ Plug integrity __ BOP Test __ Location clearance__ Mechanical Integrity Test ~ Subsequent form required I_¢IN Approved by order of the Commission Robert N. Christenson ' ~'i .,judmmissioner Form 10-403 Rev. 06/15/88 /ti t..- Date Submit In Triplicate TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 1, 1998 Mike Miller Badami Drilling Team Leader BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Badami Unit B 1-15 BP Exploration (Alaska), Inc. Permit No.: 98-074 Sur. Loc.: 3855'NSL, 117~JqEL, Sec. 8, T9N, R20E, UM Btmhole Loc: 2129'SNL, 312'WEL, Sec. 5, T9N, R20E, UM Dear Mr. Miller: 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. Your request for a diverter waiver is approved. All production is to be reported to this well; none shall be reported to laterials. 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 ma3' witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North David W. Chairman BY ORDER OF THE COMMISSION dlf/encl osures cc: Department of Fish & Game, Habitat Section w,"o encl. Department of Environmental Conser~'ation w/o encl. STATE OF ALASKA ALASKA-~-o-iL AND GAS CONSERVATION COk-~lSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work l~ Drill DRedrill Ilb. Typeofwell DExploratory [-I Stratigraphic Test Ci~ Development Oil [] Re-Entry [] Deepenl []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 54.4' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 367011 4. Location of well at surface 17. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3855' NSL, 117' WEL, SEC. 8, T9N, R20E, UM Badami Unit At top of productive interval 8. Well Number Number 2S100302630-277 2239' SNL, 488' WEL, SEC. 5, T9N, R20E, UM B1-15 At total depth 9. Approximate spud date Amount $200,000.00 2129' SNL, 312' WEL, SEC. 5, T9N, R20E, UM 05/01/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 365533, 312'I B1-14, 6.93' at 400' MD 2533 12641' MD / 10800' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11440' MD Maximum Hole Angle 46° Maximum surface 4400 psig, At total depth (TVD) 10094' / 6326 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-Mod 4519' 35' 35' 4554' 4554' 2850 sx PF 'E', 350 sx Class 'G' 8-1/2" 7" 29# USS95 BTC-Mod 11167' 33' 33' 11200' 9601' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC 391' 11150' 9565' 12641' 10800' Uncemented Slotted Liner !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 MD TVD Structural Conductor Surface Intermediate Production Liner RECEJvEB ORiGiL1AL Perforation depth: measured /~,PR 09 1998 true vertical ;~as~(a 0ii & Gas 00tls. 00mllrlissior~ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketc'~ne'h0ra~]b~" Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mike Miller, 564-5066 Prepared By Name/Number: Kathy Carnpoamor, 564-5122 121. I hereb¥.~ertify that the fo_.~oing is true and correct to the best of my knowledge Signed ~ ~~~ Mike E. Milller Title Badami Drilling Team Leader Date Commission Use Only q~- 0-/"~ 50- ©~ - ~ 2,.. ~'~o~ - (~O ~'-~'[_¢;2f'~' forother requirements Conditions of Approval: Samples Required []Yes [~ No Mud Log Required []Yes []No Hydrogen Sulfide Measures I--lYes[~No Directional Survey Required [~Yes []No Required Working Pressure for BOPE []2M; 1-13M; r-15M; J~'10M; []15M Other: Approved By T~/'- ~;fi'~ ~,~:~:t:::> ~1~1~-~~ drl~irla, Si?flh0U ~oVmmissioner by order of the commission Date~,--/ Form 10-401 Rev. 12-01-85 Submit In Triplicate B 1-15 Producer - Multi-lateral PERMIT Bl-15 - HOLE//3 - PRIMARY WELLBORE - Third penetration below 7" intermediate casin~: I TD MD: 112641 J lTD TVDBRT: 110800 Badami Sand A5 Primary 2239'FNL 488' FEL SEC 5, T9N, R20E, UM, AK tar[let -* Bottom Hole Location .(TD) 2129' FNL 312' FEL SEC 5, T9N, R20E, UM AK Formation Markers: Formation Tops MD TVD (bkb) Remarks Shallowest Badami Sand 10827 9328 Badami Sand J2 10550 9858 Badami Sand X3 11677 9965 Badami Sand F5 11874 10135 Badami Sand A5 12254 10464 Primary Sand Badami Sand Q5 12494 10672 Total Depth 12641 10800 Casing/Tubing Program: Hole ~;ize ' Cs'g/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. . MD/TVD MD/TVD brt 6" 4-1/2" 12.6# L-80 BTC 391 11150/9565 12641/10800 slotted liner (A5-TD) Tubing 4-1/2" 12.6# L-80 IBT 9672 33/33 11100/9528 Mod. Lo[l[lin[l Program: Production Hole RFT Cased Hole Logs: MWD GR/Resistivity; Run 1 - HDIL/ZDL/CN/MAC; Run 2 - MIRL; Run 3 - STAR 2 fluid, 10 pressures none Directional: KOP: 111440'md/9775'tvd @ 46 deg Maximum Hole An[lie: Close Approach Well: 46 deg @ kop B1-01 ,B1-11 ,B1-18,B1-14 and B1-15#1 and B1-15#2 will exist Shared Services Drilling Contact: B 1-15 Producer - Multi-lateral PERMIT Mike Miller 564-5066 I Well Name: I B1-15 Well Plan Summary DATA COMMON TO ALL THREE PENETRATIONS (PR[MARY AND BOTH LATERALS): Type of Well (producer or injector): I Producer- Multi-Lateral Open-Hole I Surface Location: I 3855' FSL 117' FEL SEC 8, T9N, R20E, UM, AK I AFE Number: i ~04~ KBE: I 54.4! 28E AMSL IRig: !NabOrs Estimated Start Date: May 1,1998 [ I Well Design' Operating days to complete: I 35 Ultra slimhole- multi-lateral open hole completion w/slotted liner Formation Tops MD TVD (bkb) Remarks base permafrost 1984 1984 Top Middle Brookian (TMBK) 7429 6934 M90 8896 7944 Base West Sak (M85) 9392 8294 Casing/Tub in[i Program: Hole ~ize Csg~ Wt/Ft Grade Conn Length Top Btm Tb[i O.D. . MD/TVD MDrrVD brt 24" 20" 91.1 # H-40 Weld 80 37/37 116/116 12-1/4" 9-5/8" 40# L-80 BTC 4519 35/35 4554/4554 mod 8-1/2" 7" 29# USS95 BTC 11167 33/33 11200/9601 mod IInternal yield pressure of the 7" 29#/ft USS95 casing is 9690 psi, which is greater than the maximum anticipated surface pressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/ft, surface to 6570'; oil, 0.36 psi/ft, 6570 to 10094' tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. Loggin[i Pro[iram: IOpen Hole Lo[Is: Surface None Intermediate MWD/GR @ hole section TD Production MWD/GR/RES · planned for entire hole section Mud Program: Special desi[in considerations I displace open holes to oil based mud Surface Mud Properties- B 1 - 15 Producer - Multi-lateral PERMIT Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity. Point gel gel Loss 8.6 150 25 20 45 9 10 to to to to to to to 9.8 300 60 30 60 9.5 15 Intermediate Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel -~ Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to 10.1 55 20 10 25 9.5 4-6 Production Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~lel Loss 12.0 45 10 8 15 8.5 4-5 to to to to to to to 12.4 55 15 10 20 9.5 4-5 Well Control (Secondary): Well control equipment consisting of 10,000 psi W.P.(2) pipe rams, (1) blind rams, and 5M WP annular preventer will be installed and is capable of handling maximum potential surface pressures.10 M WP Choke & kill manifold. BOPE and drilling fluid system schematics on file. Waste Manaqement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Annular Injection: No annular injection is planned at this time. DRILLING HAZARDS AND RISKS: Wellbore proximity comments are addressed under each MLOH section. Stuck pipe ~ UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Well Control- Lower Badami sands are overpressured- mud weight of 12.4 ppg will be required below the 7" casing shoe setting depth. Maintain 6" production hole section circulation rates @ 190 gpm to prevent loss circulation problems while drilling the Badami reservoir. Monitor wellbore drilling fluid loss rates after drilling upper most Badami Sands (15-60bph), look for' wellbore to flow after initial kelly down. ! 2. 3. 4. 5. 6. 7. . , 10 11 12. 13. 14. 15. 16. 17. 18. 19. B 1-15 Producer - Multi-lateral PERMIT Badami Bl-15 Multi-lateral Proposed Summary of Operations Weld the starting head on the conductor. Prepare the location for the rig move. MIRU Nabors 28E drilling rig. Build spud mud. A diverter is not required ~y AOGCC. Drill 12-1/4" surface hole as per directional plan. Run directional MWD from surface to TD. Run 9-5/8" surface casing and cement to surface in two stages. NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi. RIH with BHA, test casing to 3000 psi. Drill out float equipment and 20' of new formation. Perform a LOT as per SSD Standard Operating Procedure. Contact the Badami Drilling Team Leader or SSD Superintendent with LOT test results before drilling ahead. Drill 8-1/2" hole to intermediate casing TD as per directional plan, with MWD directional surveys. Run 7" casing and cement as per Cement Procedure (1000' md of cement above shoe). Test BC)PE to 6000 psi. ~ · Drill out float equipment and 20' of new formation. Perform FIT to 15.5 ppg equivalent. .Drill 6" hole to B1-15 L1 - [Hole #1] target TD as per directional plan with GR/Resistivity MWD. Maintain pump rate below 200 gpm and minimize mud weight. Run 4-1/2" slotted liner (with inner string) from TD to just above the top of the amalgamated pay (exact depths to be determined from MWD logs). [This will leave open hole above top of slotted liner]. Set liner on bottom, rotate off liner running tool. Displace liner and open hole to above KOP for B1-15 L2 [Target #2] to kill-weight Oil Based Mud. [the OBM will mitigate formation damage while mud is left in the hole prior to production startup]. POH. FIIH with BHA and perform open-hole, Iow-side kickoff. Use most aggressive BHA design to get off (tricone or PDC sidetrack bit, 1.83 - 2.15 motor housing bend, etc.) Drill to B1-15 L2 [Hole #2] target TD as per directional plan with GR/Resistivity MWD. Run 4-1/2" slotted liner (with inner string) from TD to just above the top of the amalgamated pay (exact depths to be determined from MWD logs). Set liner on bottom, rotate off liner running tool. Displace liner and open hole to above KOP for B1-15 [Target #3] to kill-weight Oil Based Mud. POH. RIH with BHA and perform open-hole, Iow-side kickoff. Drill to B1-15 [Hole #3] target TD as per directional plan with GR/Resistivity MWD. This will be designated the primary wellbore. Run a 4-1/2" slotted liner from TD to above top of uppermost sand, and 4-1/2" solid liner from that point to 50" inside 7" intermediate casing, with inner string. Set liner 4-1/2" x 7" liner hanger. Release from hanger, displace liner volume to kill weight OBM. Run 4-1/2" tubing and packer. Locate packer in 7" casing as deep as possible (to get GLM's as deep as possible for efficient gas lift capability). Set packer by pressuring up to 5000 psi against the PXN plug in the tailpipe. See detailed completion procedure for details on pressures, etc. Test tubing to 3500 psi and test tubing/casing annulus to 3500 psi for 30 minutes, record. Pull SSSV dummy, shift sliding sleeve. Install dummy in top G/L station. B 1-15 Producer - Multi-lateral "~--' PERMIT 20. Pump down the tubing, displacing mud with fresh water treated with corrosion inhibitor. Place a diesel cap on the tubing and tubing-casing annulus to freeze protect to 2200' tvdss. 21. Close the sliding sleeve. 22. Set BPV 23. ND BOPE, NU tree, pull BPV. 24. Install two-way check, test tree to 5000 psi for 30 minutes. 25. Freeze protect the outer annulus by downsqueezing. -' 26. RD/MO Nabors 28E rig, release rig. Transfer custody of well to Operations. B 1-15 Producer - Multi-lateral PERMIT Badami B1-14 CASING SIZE: 9-5/8" SPACER: SURFACE CASING CEMENT PROGRAM - HALLIBURTON 50 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 350 SACKS YIELD:2.17 ft3/sx M IX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from 750' above the casing shoe to the ES cementer at 2200' md, plus 50% excess. Premium 2% calcium chloride 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 350 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 750' md of fill in the gauge hole plus 50% excess plus 80' shoe joint. SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YI ELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 2500 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE' Permafrost E NOTE: WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: To be determined on job x job basis B 1-15 Producer - Multi-lateral PERMIT Badami B1-1~' INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE' 7" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 185 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. B 1-15 Producer - Multi-lateral PERMIT MULTI-LATERAL WELL ABANDONMENT PROGRAM The following program is to be used at such time as the wellbores below the 7" intermediate casing are to be abandoned. 1. MIRU Rig. 2. Kill Well. 3. Pull tubing, packer, completion. 4. RIH with 7" EZSV cement retainer and set 50-100' inside the 7" intermediate casing and above all perforations in the 7", if any exist. 5. Mix and pump a volume of premium class G cement to fill the 7" casing below the EZSV and the calculated volume to fill the entire hole section of all wellbores below the 7" shoe, plus 10%. 6. Unsting from EZSV. 7. Pressure test the EZSV and cement to 3000 psi. 8. Procedures for the remainder of the wellbore above the EZSV will depend on the future plans for the wellbore (total abandonment, sidetrack, etc.). 10 Kelly bushing to wellhead/GL (fi) 35.3 Wellhead to sea level (fi) i:: i911. B1-15 L2 B1-15 Conductor 20.000 19_124 91.5 .ES'X' Sa~e~y W've ~d~ng,~.~e 4.5 3.813 Surface Casing 9.625 8.681 40 i.i: ~ C~rnco 4 1/2' x 1' GLM ... ;..~::::~.~:::.~;~%~.._..-.~.>~..~ Camco 4 1/2' x 1" GLM Camco 41/2' x 1" GLM RES 'TN-r' Permana'Tt Packer 5.875 3.958 23-29 ~;~.~.~;:.~!,11024.7 HES 'X= Landing Nipple 3.813 :;;~;~i~;~.~.<~ ~?t.::ii~ 11044_7 HES 'X]q' Landing Nipple 4.5 3.725 ~i~! i~:.~;.i~. 11054.7 Wire[ine EntryGuide 5.25 3.958 i~i~i~;~,~:?~8~:~'~ 11064.7 Top slotted Liner Hanger 7 i~:~ i~;:;ii~ 11114_7 Intermec~ate Casing 7.000 6.184 29 Kick-off point Z.}~i..~..~i!!~' :~i!;i.~ 11404.7 M id rese~oir for G L ~sign . i: ~?~!!! :~.:~;~ ::! 12214.7 Slotted ~,~r 4.5O0 3958 12_~ Date Rev by Comments .,.s.~e B.Turnbull IrY~.SLI design sp._r,r,~ ~n [ sn~,~ s~,~. o~,,~ D rillQ u est' [ Pro~sal O~ for B1-15 Wp10 ~ S~le: a~ach = 30~ Eastings ~ V~ O~iq: Well ~n~ -~ -30~ ~ kle~u~m~ un~: ~ -.. I . I , : ~ ~: Well ~emq~ Ve~ ~ OFFS' ~E m ~ - 4650 ........................ 4 1/2 Liner - 1:~[64 MD, 1~0.00 ~D: ~ 12J24.M ~0.~ ~.~3 E~5.21 ~55.~ N 3LOJt W ~fi51.3~ 0,~ ~ [ ~ ~ l~nl~ 3~ ~.~J )~.~ 457~.93X ~4W ~814.0S 0.~ ~ ~m ~ 1 / l~l~'D-~J3.40ff, 31&51 l 9750' -w~[R~e 1~'/[~: 11~0~MO, 9~5.~fl~D ~ .... ~' ~7 ~ 12.~/10~:11~ M[~,~4~ .. C~n~nae~rO ~0~:11~0.C~.D,~.~fl~O 4,0~0 '~le:.~h ~ ~h 4050 ~::----~ .... ~::~::z:zz::~::~::] ::~: ~ ~ - ........ 2~~~~ 2/., .......................... ~.-o.~ PR[LIMI ~RY xo6so - ! ~ ~ / ,.0,.~. ~4 1/2" Un er -12641. 64 MD, 108~.00 ~D mm I ....... ~_.~ To~ ~M~: ,2~1.~ LID. ~ ~ ~ SURFACE LOCATIOH PLOT DATE: 10950 - R~: ~. ~ ~ ..... ~ R~;~L ~- 3150 ~50 3750 4050 [ ~s.~ ~: ~le: (inch = 30~ VeRi~! Senior ~on ~imuth: ~X,Oe0~ (True ........ . . FOR Badami Measured Depth (fi) PRELIMINARY PERMITTING ONLY hqcl. Azim, Sub-Sea Depth (fi) Vertical Depth (ft) '[ 1440.00 45.537 345.000 9721.06 9775.46 11500.00 40.426 350.546; 9764.59 91318..99 11520.00 3 8.457 352.705 9780.04 91334.44 11550.61 36,357 30-7.681 9804.36 91358.76 11600.00 33.491 6.744 9844~7 9B99~----~ 11607.29 33,126 8.193 9850.97 9905.37 11700.00 30,158 28.730 9930.12 :9984.52 11747.03 30,000 40,000 9970.85 10025.25 11800.00 30.000 40.01)3 10016.72 10071.12 11866.74 30,000 40,000 10076.?_5 10130.65 11900.00 30,000 40,000 10103;32 10157.72 12000.00 30.000 40.000 10189.92 10244.32 12089,29 30.000 40,000 1026725 10321.65 12.100.00 30.000 40.00,0 10276_53 10330.93 12200.00 30.000 40.O00 10363.13 10417,53 12300.09 30.000 40.000 10449.73 10504.13 12324.34 30.000 40.~00 10470.81 10525.21 2400.00 30.000 40,000 10536~3 10590.73 2418.03 30.000 40.000 10552.00 10606.40 2500.00 30.000 40,000 10622.94 10677.34 12600.00 30.003 40.000 10709,54 10763.94 12641.64 30.003 40.000 10745.60 10800.00 Sperry-Sun Drilling Services Proposal Report for B1-15 Wp 10 ~ Your Ref: B1-15 Hole ~3 Alaska State Plane Zone 3 Badami CPF Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (.) (lQ (o/to~) (~) Comment 4063.74 N 513.41 W 4104.02 N 522.25 W 4116.59 N 524.11 W 4135.10 N 525.68 W 4163.29 N 524.67 W 4167.26 N 524. ! 5 W 4212.90 N 5DCJ.30 W 4232.28 N 496.06 W 4252.57 N 479.03 W 4278.90 N 456.9¢ W 4290.87 N 446.89 W 4329.17 N 414.75 W 4363.37 N 3B6.06 W 4367.47 N 3B2.61 W 4405.78 N 350.48 W ~.~..08 N 318.34 W 4453.40 N 31;0.5! W 448~.38 N 286.20 W 44B9.31 N 280.38 W 4520.68 N 254.06 W 4558.99 N 22~.92 W 4574.93 N 208.5¢ W 591049L35 N 363455.27 E 3218.88 5910537.78 N 363447.15 E ! 2.000 3248.85 5910550.38 N 363445.52 E [2.000 3258.67 5910568.92 N 363444.28 E 12.000 3273.73 5910597.08 N 363445.79 E 12.000 3298.41 5910601.05 N 363446.38 E 12.000 3302.08 5910646.41 N 363462.05 E 12.000 3348.85 5910665.55 N 363475.64 E 12.000 3372.28 5910685.53 N 363493.03 E 0.000 3398.44 5910711.46 N 363515.59 E 0.000 3432.39 5910723.25 N 363525.85 E 0.000 3447.83 5910760,96 N 363558.67 E 0.000 3497.21 5910794.64 IX/ 363587.98 E 0.000 3541.30 5910796.6B N 363591.50 E 0,000 3546.59 5910836.40 N 363624_32 E 0.000 3595.98 5910874.12 Iq 363657.14 E 0.0OO 3645.36 5910883.30 N 363665.~3 E OX]iX) 3657.38 5910911.84 N 363689.96 E 0.000 3694.75 5910918.66 N 363695.90 E 0,000 3703.68 5910949.56 N 363722.79 E 0,000 3744.13 5910987.28 N 363755.65 E 0.(KIO 3793.52 591i002.98 N 363769.27 E 0.00O 3814.08 '1~e-on, Slarl Dir @ 12.090=110Oft: 11440.00ft MD, 9775.46ft TVD C~ntlnue Dir @ 12.000°l100ft: 11520.00ft MD, 9834.44ft TVD J2 X3 End Dir, Sail @ 30.000°: 11747.03fl MD, l(K]25.251t TVD F5 A5 TB~argel: 12324.34ft MD. 10525.21 fi 'FVD se A5 (TARGET DEPTH) Target: B1-15 Lateral 2, 200.00 Radius., Geologica) 05 Total DeDth · 12641.64fi MD, 10800.0Oft TVD 4 I/2' Litter Continued_. 7 Aprit, 1998- 9:08 - 1- Dr/l/Quest Sperry-Sun Drilling Services Proposal Report for B1-15 WplO I~ Your Ref: B1-15 Hole ~3 Badami All data is in feet unless otherwise stated. Directions and coordinates are re=tative to -I'rue North. Vertical depths are relative to Well Reference. Northings end Eastings are relative to Well Reference _ The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 31.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12641.64ft., The Bottom Hole Displacement is 4579.68ff., in the Direction o! 357.390° (True)_ Alaska State Plane Zone 3 Badami CPF 1938.9:08 - 2 - Dr~tlC}uest rlffi, U! ,30 IUl'. U,.~,,",J rill DI'I. MM~,i-DUI1 rlL, l-ldlM"l I'l'l^ Pig, I~UIUU.,,,JUIU~ l, Ut" Shared Services Drilling Greg Hobbs 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Approved Well Close Approach Review P2-09 Wp3 C.,-a'¢g, Tile above mentioned well has been scanned using standard anti-collision methods via DEAP, I _ __ I III · Tim scan was performed with the following parameters: Start Scan Inspection Zone End Scan Inspection Zone 12,498._4.~ ' _ Starting Scan Radius 200.00 ' Rate et' Radius Increase (per 10009 100.00' Antl.CollL~ion Scan summary: At the planned KOP the Starring Scan Radius is I00' larger tllan DEAP's default seUmg$ of 100' Start Scan Radius increasing at 50' per 1000 'MD for a new-drill well scan, thus DEAP's defaull3 would be equal to 100' at the Start Scan Inspection Zone as slated above. These numbers are used to produce a final scan radius of 1449.843' which is 724.9215' larger than DEAP's default value of 724.9215' _Jl _ II I .... II II _ II - At this enlarged rad[u,~ ~ following wells were dete~ted <luring tile scan (Ba~ed on Closest 'Allowable Deviation from Plan'): No~e: ~I~L~ list may not inelud~ all tl~c, wvlls detected, only thos~ of which are of conc:m or may effect Tolecanco Lino drawi_n~l 1t1-11 Bl-ll B]-I4 BI.18 0,00 'MD 3100,00 'MD 400.19 'MD 999,84 'MD 5192.41 'MD 599.52 'M D 139,39' 265.00 ' No WeJ! b not on-line yet ,, 39,71 ' 268,75 ~ Da~ (akon,l¥om $i~'~. Suit 69,70 ' ~9.56 ' ~ue topr~lmt wilh BP's D~ Minor Minor Minor Minor Minor Minor Minor 10,78 ' 273.70 ~ 5.93 ' No Well i~ not on-line yet B1-21 30.20' 97.30 ' 20,51 ' 106.42' 162.,80 ° 59,02 ' 55,'28' 94,50 ~ 50.32 ' No Well Lc not. p.n-line yet No Well is not oa-line yet ,, No W. dl b not oMino ]/et , i . , i _ II · II i Tolerance Plot required: Close Apl>roach Comments: -- · i il ii YES · _llj _ I I Close Approach Scan Performed by: Checked by: Approved by: I January 27, .1998 B1.15 Wpl0.xls _ AWD Proximity Review r ~ 4/7198 The Surface hole (0.2000) close approaches are as follows I11-01: 1.~2.7t;' atlow~bl~ devi~(ion ~,! ?00.6It' MO, ($htl~,-in Condi(ion) Bl-14; 6.93' allowable doviadml ai400,19' MD, (Shut-in Col~ditiOl0 B 1.1 $: 20.51' ~llownble deviation ,~I 999,84' MD. (~hul-in Condition) 151-21: $0.32/allow,'lbl~ d~vlt,km at SPP.$Z' MD, (,$htlt-i~ Condition) The Deep hole (z00o. mD) close approaches are ns follows Dl-ll.' ' ~,llowablc dcvi~on ,'a 3100' MD. (~hut-il~ CoMitlon) B1-15 WplO.xls_ AWD Proximity Review 4/7/98 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 02:1.708 CKO21798F :tO0. O0 :tOO. O0 HANDL,INO INST' s/h kathy campoa~o~- x 512~ .... ~-rAcHFn eH;OK IS IN PAYME~ FOR ~MS DE~RIBEO ABOVE. IltlYlll I 1 dO OO 1 OO. OO ,/ ~z/~ (T2 o3 N A .......................................................................... ..f.]. //m./. .............. N J,, -T// /f ~/ N ,k N ,k ..................................................................... 'alqeqmd se6 Sql 1o a311as;:~Jd ......................................................................................................................................................... 'UMOplmtS uo!leJado lnotll!M Jn:)3o I1!~ '")',,! N ' (t,8 ,~e~) f:§-d~ IdWM Sa!ldujOo ploj!uuuJ a~oqo ......................................................................-"'~ ~ 5!sd <2,<~,/~) ~ ol lsal :ale MoJdde 6u!lei ssad OF, 61, ZI 91 ' ' 's/v~GsFI umOU~l lie sloaloJd pap!^oJd ~IMOt-'IS -I'JO/NO'-~ )~ © ~ 0 / #tlNI1 ()/o ~ V:l~lV -t030 '1 ha, uJed lesods!p uu~ 115@s aJoqllaM [] ^JeS [] IIJPeJ,J~i(^aP [] dxe :~V~lLgO~ld .5 / - t E/ .... .... - .......................... '-- ' ' - ' ..... '~¢£/ ii 1 Vt] XO0-10:lO ONIM33NION3 NOIIV~ILSINIIAIQV 31AIVN -I 13M ANVclI/~IO0 I$1IHO::iH3 ll~13d ll:IM ' ---- - . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. WELL COMPAN'ï' LOCAT ION
