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198-034
,%', //7.4' • • ,%, yyTHE STATE Alaska Oil and Gas of LASICAL Conservation Commission .Et _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `* Main: 907.279.1433 O �P ALAS Fax: 907.276.7542 www.aogcc.alaska.gov June 20, 2016 Mr. David Kumar Production Manager Savant Alaska, LLC 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 RE: No-Flow Verification JAN 0 4 2017 Badami B1-11A PTD 1980340 Dear Mr. Kumar: On May 8, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Badami Unit B1-11A 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 B1-11A prior to the test. The well performance was monitored for three hours with resulting in gas flow rates up to 200 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 in 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 B1-11A 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, U ' ?G 70'7? James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: May 8, 2016 P. I. Supervisor FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector Badami B1-11A Savant - PTD 1980340 - May 8, 2016: Travel to Badami on 70 degree North 207 plane. I arrived at Badami at 12:00 and was met by the Lead Wells Supervisor Dan Clark. He rigged up the flow meter to the well and I verified the IA was open and tied into the tubing. All valves were in the open position and well was at ZERO pressure. Well pressures prior to starting test were T/I/O = 0/0/0. The following table shows test details: Time Pressures Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 12:30 0 0 0 Start Test 13:30 0 0 0 Not enough gas to register on flowmeter 13:35 0 0 0 Close valves and monitor for 1 hour 14:35 0 150 CFH 0 Bled down to 80CFH in 1 min. 40 sec. 14:40 0 0 0 Close valves and monitor for 1 hour 15:40 0 200 CFH 0 Bled down to 100 CFH in 1 min. 55 sec. 1 Pressures are T/IA/OA at 15:40 = 0/0/0 - Summary: There was no liquid on any of the bleed downs. Badami B1-11 Aexhibited the characteristics for a no-flow determination. Attachments: Photos (3) SCANNED DEC 162Vi5 20 16-0508_No-Flow_Badami_B1-11 A_bb.docx Page 1 of 3 • • No Flow Meter—calibration certificate ,t '- \., . .. rit.:,...... __—.tin ....„,f c. 1 x r. '„-:-.4 4 4 „1-100. At} Certificate ill This is to certify that this instrument - has been calibiated for the fluid ^% onditions specified on the purchase er and embossed on the nameplate. assuring devices that are traceable to the united States National Institute for Standards and Technology(NIST- formerly National Bureau of Standards) were used for this calibration. � S,f'( 'I Technician �`i5 /S2 Instrument Serial Number EROCO Engineering Corporation 721 Custer Av a Post Office Boz 6316 Evanston,IL 60204.6318 115A r 2016-0508_No-Flow_Badami_B 1-11 A_bb.docx Page 2 of 3 • • No Flow Test equipment • 47, ark 7 2016-0508 No-Flow Badami_B1-11A_bb.docx Page 3 of 3 ; 1 (- 11/v (' (ctSO 34-G Regg, James B (DOA) From: Regg, James B (DOA) ZivtI(te Sent: Wednesday, February 24, 2016 2:31 PM To: David Kumar Cc: DOA AOGCC Prudhoe Bay Subject: RE: Update at Badami and Osprey - Request for K-valve use Attachments: AOGCC Test Witness Notification Request: SVS, Badami, B1-11 and B1-21 Thank you for the details about the replacement K-valve for Badami B1-11A(PTD 1980340). As discussed by phone, Savant can bring B1-11A back on line with the replacement K-valve. We have received the notice for testing on Friday; one of our Inspectors on the Slope will advise of our intent to witness. Jim Regg Supervisor, Inspections AOGCC SCANNED MAR 1 `r 2016 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: David Kumar [mailto:David.Kumar©cookinlet.net] Sent: Wednesday, February 24, 2016 8:53 AM To: Regg, James B (DOA) Subject: Re: Update at Badami and Osprey - Request for K-valve use Mr. Regg, We have the K-valve onsite at Badami. It is the same make and model as the previous one (Please see attachment 1).The dome pressure is set higher at 300psi based on the recommendation of the specialist after looking at our operating conditions and performance of the previous K-valve.This will make it close faster than the one we were using which had a dome pressure set at 180 psi. I have also attached operating conditions (attachment 2),which was part of the previous sundry application. We had a recent survey done on 1/15/2016 and the only difference was the temperature at the valve was 5 deg F higher than the Oct, 2015 condition.We are requesting approval to get the well online and go perform an in-house closure test. We will let the Commission know of the results immediately and schedule a witness.The well is currently shut-in. Thanks and Regards David Kumar Production Manager Cook inlet Enrgy- 1 • • Regg, James B (DOA) From: Steve Sage <noreply@formresponse.com> Sent: Wednesday, February 24, 2016 2:19 PM ;-Z(ZIA I(e To: DOA AOGCC Prudhoe Bay Subject: AOGCC Test Witness Notification Request: SVS, Badami, B1-11 and B1-21 Question Answer Type of Test Requested: SVS Requested Time for 02-26-2016 2:30 PM Inspection Location Badami, B1-11 and 131-21 Name Steve Sage E-mail steve.sage@Savantalaska.com Phone Number (907) 659-1349 Company Savant Alaska We would like a field inspector to witness the performance Other Information: retesting of our SSSV (K-Valve) on B1-11A and the SSV on B1-21. Submission ID: 332165148411184943 i • 110 1Lti (A- PT') i<i ;4{ Carlisle, Samantha J (DOA) From: Regg, James B (DOA) Sent: Wednesday, February 24, 2016 9:22 AM 9 24ZA(i4- To: Carlisle, Samantha J (DOA) Subject: FW: Update at Badami and Osprey - Request for K-valve use Attachments: Badami Kvalve 2-23-16.pdf; Previous and Present Operating Conditions of the K.docx Not sure who is responsible for Badami but I will take care of this. 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: David Kumar [mailto:David.Kumar@cookinlet.net] Sent: Wednesday, February 24, 2016 8:53 AM To: Regg, James B (DOA) Subject: Re: Update at Badami and Osprey - Request for K-valve use Mr. Regg, We have the K-valve onsite at Badami. It is the same make and model asthe previous one(Please see attachment 1).The dome pressure is set higher at 300psi based on the recommendation of the specialist after looking at our operating conditions and performance of the previous K-valve.This will make it close faster than the one we were using which had a dome pressure set at 180 psi. I have also attached operating conditions (attachment 2),which was part of the previous sundry application. We had a recent survey done on 1/15/2016 and the only difference was the temperature at the valve was 5 deg F higher than the Oct, 2015 condition. We are requesting approval to get the well online and go perform an in-house closure test. We will let the Commission know of the results immediately and schedule a witness.The well is currently shut-in. Thanks and Regards David Kumar Production Manager :FerE; 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 907-433-3822(Direct)1907-903-4164(Mobile) 1 907-334-6745(Main) 1907-334-6735(Fax) S • David.Kumar@cookinlet.net From:<Regg>, "James B (DOA)" <jim.regg@alaska.gov> Date: Monday, February 22, 2016 at 9:38 AM To: David Kumar<david.kumar@cookinlet.net> Subject: RE: Update at Badami and Osprey Same make/model for K-valve? If so, then just need confirmation that the approved settings per Sundry---are the same and you can install without additional approval. Different K-valve will require additional approval Osprey—Wednesday or later would work. 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: David Kumar [mailto:David.Kumar@cookinlet.net] Sent: Monday, February 22, 2016 8:59 AM To: Regg, James B (DOA) Subject: Update at Badami and Osprey Dear Mr. Regg, Badami We retrieved the K-valve over the weekend after a few tries and found a piece of shear stock stuck in the K-valve on B1-11A. We also tried an in-house no-flow test and failed on the gas side. We then reinstalled the K-valve and tried another closure test and failed.The well was shut in immediately following that. We do have another K-Valve in route to Badami. Could you please give us guidance on path forward to get the Commission to approve use of it? Osprey We conducted in-house testing on the SVS system for RU-2A. Please let us know when is a good date to witness and we will fill in the web notification form Thanks and Regards David Kumar Production Manager Coale Inlet Enemy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 2 S • • 907-433-3822(Direct)I 907-903-4164(Mobile) 907-334-6745(Main) 1907-334-6735(Fax) David.Kumar(a,cookinlet.net 3 • • POLLARD WIRELINE INC . Shop Location: Mailing Address: 42320 Kenai Spur Highway P. 0.Box 1360 Ph. (907)283-7006CillKenai,Alaska 99611 Fax(907)283-7118 (907)283-7006 NOTE: Redressed Halliburton k-valve and reset dome pressure to 300 psi. Tested on the rack and it fully shut and held. Field: Badami Well NO: B1-11A Test Date: 2/20/2016 SN: 0859703 Dome Pressure: 300psi • • Previous and Present Operating Conditions of the K-Valve 4(`j " Kvitcut- Previous Conditions 2011 • Pressure- 400.75 psi @ 2212' MD • Temperature- 39.54 degF @ 2212' MD • Original k-valve dome pressure set @ 333 psi Present Conditions 2015 • Calculated pressure at the k-valve - 408 psi @ 2212' MD • Estimated temperature at the k-valve- 40 degF @ 2212' MD • Flowing Temperature - 70 degF • Flowing Pressure- 195 psi • Flow Rate- 263 BOPD • Oil Density- .9187 g/cm^3 • Produced Gas Density- .687 g/cm^3 • TVD - 2142' • K-valve dome pressure set @ 180 psi (Set due to lower separator pressure —132 psi) • *A, —I( p, la`603L Regg, James B (DOA) From: Regg, James B (DOA) Z I ZZ i G0 Sent: Monday, February 22, 2016 9:38 AM / 1 To: 'David Kumar' Subject: RE: Update at Badami and Osprey Same make/model for K-valve? If so,then just need confirmation that the approved settings per Sundry---are the same and you can install without additional approval. Different K-valve will require additional approval Osprey—Wednesday or later would work. Jim Regg Supervisor, Inspections ttNE° SEP 2 3Z015 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:David.Kumar(acookinlet.net] Sent: Monday, February 22, 2016 8:59 AM To: Regg, James B (DOA) Subject: Update at Badami and Osprey Dear Mr. Regg, Badami We retrieved the K-valve over the weekend after a few tries and found a piece of shear stock stuck in the K-valve on B1-11A. We also tried an in-house no-flow test and failed on the gas side.We then reinstalled the K-valve and tried another closure test and d failed.The well was shut in immediately following that. We do have another K-Valve in route to Badami. Could you please give us guidance on path forward to get the Commission to approve use of it? Osprey We conducted in-house testing on the SVS system for RU-2A. Please let us know when is a good date to witness and we will fill in the web notification form Thanks and Regards David Kumar Production Manager Cook lair,tblew 001 \ , 5t11 'bait' 110, \ncii(m12c. 'ala 09501 o0-..I 11 r`22i)11cct�,9t)--{)0 I b Mobile) 1 v,OF T7J� • • �w\��\��y,'s� THE STATE Alaska Oil and Gas 614.-- - � /�O�T AsK Conservation Commission ` ii" _- 333 West Seventh Avenue \TM'.' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O�ALAS ¢' Fax: 907.276.7542 www.aogcc.alaska.gov January 11, 2016 ....r_ . . Mr. Leland Tate Interim COO Miller Energy Resources, Inc. 601 W. 5th Avenue STE 310 SCANNED JAN 1 4 2W6 Anchorage, AK 99501 Re: Docket Number OTH-15-027 Closeout—Notice of Violation Badami B1-11A (PTD 1980340) Unauthorized Installation of an Alternate Subsurface Safety Valve Dear Mr. Tate: Savant Alaska LLC (Savant) provided information to the Alaska Oil and Gas Conservation Commission (AOGCC) by letter dated December 3 and email dated December 31, 2015 in response to a notice of violation for the unauthorized installation of an alternate subsurface safety valve.1 Information provided satisfies the obligations of the notice of violation. AOGCC closes its review and action regarding this notice of violation. Sincerely, Cathy . Foerster Chair, Commissioner cc: D. Kumar, Savant 'Miller Energy Resources,Inc. is manager of Savant Alaska LLC Docket Number:OTH-15-027• • Closeout-Unauthorized Installation of SSCSV January 11,2016 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • Regg, James B (DOA) From: David Kumar <David.Kumar@cookinlet.net> Sent: Thursday, December 31, 2015 9:05 AM (7 hI To: Regg,James B (DOA) Subject: Re: Badami B1-11A Response - Training Materials Mr. Regg, Please see responses in Red Thanks David K From: Regg, James B (DOA) Sent: Friday, December 11, 2015 4:04 PM To: David Kumar(David.Kumar@cookinlet.net) Subject: Badami B1-11A Response -Training Materials Noticed a couple of items in training materials attached to Savant's letter 12//3/15; unclear if the differences are intentional. Since the slides do not have page numbers I will refer to by the title. Please clarify: "When is a SSSV Required"—Slide references 600 feet from the list(a)—(h); regulation uses 660 ft.That was a typo. Training Material has been corrected to reflect the change. We will also send out a memo to the field "Well Safety Valve System Testing"—Slide references CIE Production Manager; should this be Savant Production Manager or just Production Manager(as used elsewhere)? 'here has been reorganization under Miller Energy and subsidiaries post bankruptcy.CIE Production Manger/Production Manger/Savant Production Manger are the same person who will be point of contact for AOGCC production practices "Well Safety Valve System Testing"—Same slide as above; indicates the Production Manager will submit the online AOGCC Test Notification. Attachment 2 (Decision Matrix) indicates this is the Lead Operator responsibility. It is irrelevant who does it from our perspective but your training materials should match the Decision Matrix. It should have been either.The production manger normally submits notification and tracks responses. In some cases scheduling/logistics is transferred to the Lead Operator.There is good communication between the leads and the production manger on the entire SVS testing process to make sure nothing gets dropped 1 "When to Perform SVS Testing"—Refer to Guidance Bulletin 10-04 for clarification regarding the additional 30 days to complete testing beyond every 180days. Delaying SVS testing past the month due (1) requires justification, and (2) does not reset the test months.We understand that any anticipated delay requires us to immediately contact the Commission and doesn't reset the clock.Sepical emphasis was made on timing during the training "No-Flow Testing Approval"—Slide references CIE Production Manager;should this be Savant Production Manager or just Production Manager(as used elsewhwere)?Please see above "No-Flow Test Criteria"—same comment regarding CIE Production Manager. 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. 2 • i Regg, James B (DOA) From: Regg, James B (DOA) �zJ ' Sent: Wednesday, December 30, 2015 10:57 AM (�( To: David Kumar(David.Kumar@cookinlet.net) Subject: RE: Badami B1-11A Response -Training Materials As a reminder, Savant must address the items below and provide documentation before AOGCC can close out the Notice of Violation. 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 iim.reggPalaska.gov. From: Regg, James B (DOA) Sent: Friday, December 11, 2015 4:04 PM To: David Kumar (David.Kumarftcookinlet.net) Subject: Badami B1-11A Response -Training Materials Noticed a couple of items in training materials attached to Savant's letter 12/13/15; unclear if the differences are intentional. Since the slides do not have page numbers I will refer to by the title. Please clarify: "When is a SSSV Required"—Slide references 600 feet from the list (a)—(h); regulation uses 660 ft "Well Safety Valve System Testing"—Slide references CIE Production Manager; should this be Savant Production Manager or just Production Manager(as used elsewhere)? "Well Safety Valve System Testing"—Same slide as above; indicates the Production Manager will submit the online AOGCC Test Notification. Attachment 2 (Decision Matrix) indicates this is the Lead Operator responsibility. It is irrelevant who does it from our perspective but your training materials should match the Decision Matrix "When to Perform SVS Testing"—Refer to Guidance Bulletin 10-04 for clarification regarding the additional 30 days to complete testing beyond every 180days. Delaying SVS testing past the month due (1) requires justification, and (2)does not reset the test months "No-Flow Testing Approval"—Slide references CIE Production Manager; should this be Savant Production Manager or just Production Manager(as used elsewhwere)? "No-Flow Test Criteria"—same comment regarding CIE Production Manager 1 4. • 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. 2 • Regg, James B (DOA) From: Regg, James B (DOA) Z1i1I i b Sent: Friday, December 11, 2015 4:04 PM To: David Kumar(David.Kumar@cookinlet.net) Subject: Badami B1-11A Response -Training Materials Noticed a couple of items in training materials attached to Savant's letter 12//3/15; unclear if the differences are intentional. Since the slides do not have page numbers I will refer to by the title. Please clarify: "When is a SSSV Required"—Slide references 600 feet from the list (a)—(h); regulation uses 660 ft "Well Safety Valve System Testing"—Slide references CIE Production Manager; should this be Savant Production Manager or just Production Manager(as used elsewhere)? "Well Safety Valve System Testing"—Same slide as above; indicates the Production Manager will submit the online AOGCC Test Notification. Attachment 2 (Decision Matrix) indicates this is the Lead Operator responsibility. It is irrelevant who does it from our perspective but your training materials should match the Decision Matrix "When to Perform SVS Testing"—Refer to Guidance Bulletin 10-04 for clarification regarding the additional 30 days to complete testing beyond every 180days. Delaying SVS testing past the month due (1) requires justification, and (2) does not reset the test months "No-Flow Testing Approval"—Slide references CIE Production Manager; should this be Savant Production Manager or just Production Manager(as used elsewhwere)? "No-Flow Test Criteria"—same comment regarding CIE Production Manager 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. 1 • • SAANT 2015 ALASKA December 3, 2015 Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage,Alaska 99501-3572 Re: Docket Number OTH-15-027 Badami B1-11A (PTD 1980340) Unauthorized Installation of an Alternate Subsurface Safety Valve Dear Commissioner Foerster, Thank you for providing us with the opportunity for an informal hearing related to B1-11A Docket Number OTH-15-027. Miller Energy Resources Inc., as Manager of Savant Alaska has conducted an internal investigation into the above referenced matter and has come up with the following observations and corrective actions. The sequence of events leading up the issuance of Notice of Violation for the B1-11A well and our earnest efforts to prevent such problems in future was explained to the Commission during the informal meeting on Nov 13, 2015. Some of the key points have been summarized as follows: a. Badami personnel did understand that the addition of perforations to the B1- 11A well would negate the previously conducted no-flow test and were acting in good faith based on the previously approved Sundry 315-551 which requested permission to add perforations. It was stated in this Sundry application that it was our intention to install a K-Valve or conduct a no-flow 601 West 5th Avenue, Suite 310,Anchorage,AK 99501 Main (907) 334-6745 I Fax (907) 334-6735 1 • SAVANT ALASKA test post perforations. There were no comments received from the Commission objecting to use of the K-Valve.This was the same K-Valve which was initially authorized for use by the Commission before the no-flow test. b. There were efforts to install the K-Valve before the end of 14-day window. Due to cleanup operations post-perforations,buildup of paraffin in the tubing and additional cleaning runs, the installation was unsuccessful and was delayed by an additional 3 days. A closure test was duly conducted and results were transmitted to the Commission as soon as the valve was installed. Unfortunately, the delay and a request for extension were not communicated to the Commission, which was identified as a shortcoming that needed to be corrected. c. A variance through a Sundry application was immediately sought on October 21, 2015 upon hearing the Commissions disapproval of the use of the K- Valve. An open line of communication was started with the Commission and data required for making a decision was provided. A Notice of Violation at this stage was unwarranted as Savant was actively catering to the Commissions requirements to resolve the issue that was initially caused due to the miscommunication on the original Sundry pertaining to the use of K- Valve. d. The well was also shut-in immediately following receipt of the Notice of Violation on November 2, 2015. It was brought online only after hearing back from the Commission that the Sundry for K-Valve variance was being evaluated and it was satisfactory to put the well back into production. It was also brought to our attention at the informal hearing that the past history of non-compliance at Badami before Miller Energy took over operations post December 2014 was one of the contributing reasons for the issuance of the Notice of Violation. We would like to assure you that several personnel previously in-charge 601 West 5U}' Avenue, Suite 310, Anchorage, AN 99501 Main (907) 334-67451 Fax (907) 33'i-6735 2 • • SANANT ALASKA of AOGCC matters are no longer working for the company. The entire management is now in new hands and a new chain of command has been established. As part of organizational restructuring, David Kumar, who is the Production Manager for Cook Inlet Energy, was assigned responsibility for Badami production operations including AOGCC production practices starting November 2015. David Kumar has been successful in training employees and maintaining the SVS program in the Cook Inlet. He has already utilized resources and trained key personnel at Badami in matters of SVS compliance. Evidence of training key personnel is presented in the attached documents addressed to the Commission. A new chain of command has been established for Badami production operations. Similar to Cook Inlet operations for Miller Energy, Badami will be following the chain of command for SVS matters and production practices, which clearly dictates the flow of information and the key personnel responsible for maintaining an open line of communication with the Commission. Training slides used for training personnel in SVS matters is presented to the Commission in the following attachments. The training slides incorporate regulations and procedures related to SVS matters from '2015 Alaska Oil and Gas Laws and Regulations Annotated' as well as the 'AOGCC Industry Guidance Bulletin for Safety Valve Systems'. A SVS Regulatory Decision Matrix was also formulated to guide personnel through various aspects of performance testing as per 20 AAC 25.265 (h). Special emphasis has been made with regard to the timing of such decisions and communication as it previously one of the issues in our investigation. There was a lack of communication identified when delays were encountered installing the K-Valve. A simple call to Mr. Regg explaining the situation and requesting an extension could have resolved the issue and prevented the Notice of Violation. 601 /Vest 5th Avenue, Suite 310, Anchorage, AK 99501 Main (90' ) 334-6%451 Fax (907) 334-6735 3 • SART ALASKA The operators of Savant Alaska have been paying close attention to SVS matters and have been performing closure tests every other week for the last two years. Upon reviewing the SVS test sheets submitted to the state there have been no deficiencies noted since Miller Energy has taken over operations. Keeping a close working relationship with the Commission and compliance related to SVS matters is a high priority for our organization. Questions regarding this matter can be directed to David Kumar at(907) 433-3822. Sincerely, Leland Tate Interim COO Miller Energy Resources cc: Jim Regg,AOGCC Attachments 1. SVS Training Slides 2. 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THE STATE Alaska Oil and Gas �w l � ®f A SKAL Conservation Commission Witt9 -" w: 333 West Seventh Avenue 1/4 _ _ Anchorage, Alaska 99501-3572 I GOVERNOR BILL WALKER Main: 907.279.1433 Fax: 907.276.7542 ALASY'� www.aogcc.alaska.gov November 19, 2015 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 0640 0006 0779 5913 Mr. Leland Tate Interim COO Miller Energy Resources, Inc. 601 W. 5th Avenue STE 310 Anchorage, AK 99501 Re: Docket Number OTH-15-027 Badami B1-11A (PTD 1980340) Unauthorized Installation of an Alternate Subsurface Safety Valve Dear Mr. Tate: Alaska Oil and Gas Conservation Commission (AOGCC) requires the installation of a surface controlled subsurface safety valve in certain wells as described in 20 AAC 25.265(d). The Savant Alaska LLC (Savant)-operated wells within the Badami field located on the North Slope of Alaska fall into the category of wells requiring a surface controlled subsurface safety valve. Badami operations personnel notified AOGCC on October 19, 2015 that an alternate type of subsurface safety valve was installed in Badami well B1-11A on October 17, 2015.2 Installation of a subsurface safety valve other than a surface controlled valve without prior AOGCC approval is a violation of State regulations. AOGCC issued a notice of violation on October 28, 2015 for the unauthorized installation of an alternate subsurface safety valve in Badami B1-11A. By letter dated November 3, 2015 Miller Energy Resources, Inc., on behalf of Savant, requested informal review of the notice of violation. Informal review was held on November 13, 2015. Discussions included the events leading up to the issuance of the notice of violation beginning with the Badami B1-11A workover (perforations added September 30, 2015). Not only did Savant provide nothing to change AOGCC's decision to issue the notice of violation, during the course of the review additional violations were revealed including late installation of the subsurface safety valve (required to be installed within 14 days after placing the well in service; 1 Miller Energy Resources,Inc. is manager of Savant Alaska LLC 2 The alternate subsurface safety valve was referred to as a"K-valve". This subsurface controlled subsurface safety valve is normally open and remains in the open position to allow production to flow to surface. If well control is compromised,the valve is actuated closed by the characteristics of the well instead of hydraulic,electrical, mechanical or other controls from the surface. } I • • Docket Number OTH-15-027 Unauthorized Installation of SSCSV November 19,2015 F Page 2 of 2 valve was installed 3 days late) and failure to provide AOGCC opportunity to witness the initial 1 test of the subsurface safety valve. Savant'srequest for reconsideration is DENIED. Within 14 days of receipt of this letter, you are q s requested to provide the AOGCC with a written description of what has been or will be done to prevent any recurrence of these violations. Corrective actions will be subject to AOGCC f approval. This request is made pursuant to 20 AAC 25.300. Failure to comply with this request { is itself a regulatory violation subject to an enforcement action. Questions regarding this letter should be directed to Jim Regg at(907) 793-1236. Sincerely, Cathya#71a9 Foerster Chair, Commissioner cc: D. Kumar, Savant RECONSIDERATION AND APPEAL NOTICE as the As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision, r sreconsiderationsuch further tme of he AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration must riod of time smatter et out the respect in which the order ordecision it. If the notice was es believed tothen the be erroneous. be 23 days. An app ole or in part thin 10 s it is filed. e to act The AOGCC10 da granta denial of recon reconsidere application ar reconsideration in tion. the AOGCC denieshreconsideration,'upon denial,thisrorder or decision rand the on it o f reconsideration Y appealed to superior court. The appeal MUST be filed within 33 days after the date denialnwhich are FINAL and may R 30 days fbP UNLESSo on, the d AOGCC ymails,inaction,in which casetheappeal MUST be filed e AOGCC otherwise distributes, thin 40 ays after the date on which the application for h reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision be on filed within 33 will aftethe FINAL r the date on order hich the'sion of AOGCChe ma AOGCC,OR 30 days fthe AOGCC otherwiseior court. That distributes,the orderlor MUST ee s on filed within 33 day on reconsideration. t er which the ed period begins to run is not ed in In computing a periodst of time of the period od isle date of the event orin included,unless it falls on al weekend or state holiday,in which event the period runs until 5:00 the period;the last day P .m.on the next da that does not fall on a weekend or state holida . U.S. Postal Service- CERTIFIED MAIL° RECEIPT Domestic Mail Only Q' For delivery information,visit our website at www.usps.com"'. Ill • • Certified Mail Fee N $ C Extra Services&Fees(check box,add fee as appropriate) o Return Receipt(hardcopy) $ .tI 0 Return Receipt(electronic) $ Postmark O ❑Certified Mail Restricted Delivery $ Here CI ❑Adutt Signature Required $ ❑Adult Signature Restricted Delivery$ I= Postage $ —0 Total Postage and Fees s Mr. Leland Tate of Sent To Interim COO r-4 D Street and Apt.No.,ori38tioiif6.- Miller Energy Resources, Inc. f`- 601 W.5th Ave.,Ste. 310 tit);state,21P+46 Anchorage,AK 99501 PS Form 3800,April 2015 PSN 75 1 SENDER: COMPLETE ThIS SECTION COMPLETE THIS SECTION ON DELIVERY ■ Complete items 1,2,and 3. A. Signature • Print your name and address on the reverse X �— _ gent i so that we can return the card to you. ❑Addressee • Attach this card to the back of the mailpiece, B. Received by(Printed Name) C. Date of Delivery or on the front if space permits. (46)a. < +• `— (1J'/( 1• D. Is delivery address different from item 1? 0 Yes If YES,enter delivery address below: ❑ No Mr. Leland Tate Inter OO Millertnergy Resources, Inc. NOV 2 3 2015 601*-5th Ave.,Ste. 310 Anchorage,AK 99501 111'111'1 I'll iii1(III 11111 111111 III I 1E11 II 111 3. Service Type 0 Adult Signature ❑RegRsy Mail Express® 11 ❑ gistered Ma ❑Adult Signature Restricted Delivery 0 Registered Mail Restricted IlffCertified Mail® Delivery 9590 9403 0910 5223 5233 79 0 Certified Mail Restricted Delivery VYReturn Receipt for O Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery 0 Signature ConfirmationTu I Mail 0 Signature Confirmation 7 015 0640 0006 0779 5 9113 I Mail Restricted Delivery Restricted Delivery 500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • • Regg, James B (DOA) RSS Feed: AOGCC Inspection Request Posted on: Friday, November 06, 2015 11:54 AM re(t Author: AOGCC Inspection Request Subject: AOGCC Inspection Request - Submission (2015-11-06 11:53:37) Full article link: http://wwwjotform.com/submission/322652418198545869 Submission Date : 2015-11-06 11:53:37 IP Address : 24.237.228.91 Type of Test Requested: : SVS Requested Time for Inspection : 11-18-2015 11:00 AM Location : Badami Unit Name : David Kumar E-mail : david.kumar@cookinlet.net Phone Number : (907) 4333822 Company : Savant Alaska Other Information: : Please contact our Support Tech at (907) 448-1201 to schedule flights to Badami. For other information please contact David Kumar at (907) 433-3822 View article... 1 • I RECEIVED NOV 0 5 2015 LiffMiller AOGCC AVr IL Energy November 3, 2015 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Docket Number OTH-15-027 Badami B1-11A (PTD 1980340) Notice of Violation Unauthorized Installation of an Alternative Subsurface Safety Valve. Dear Ms. Foerster, Miller Energy Resources, Inc., as manager of Savant Alaska, LLC, acknowledges receipt of your Notice of Violation for Badami B1-11A and requests an informal review pursuant to 20 AAC 25.535(c). Our approved Sundry 315-511 stated our intent to either perform a no-flow test or install a K SSSV on page 4 Step 15 of the program. There was no notation, as would be normal practice by the AOGCC, either on the program or in the comment section of the 10-403 that this was unacceptable to the commission or that a separate variance request was required. We understand and fully agree that the no-flow test on October 5, 2012 negated that K valve approval on April 5th, 2011. In addition, the perforations performed in September negated the previous no-flow approval. We complied with Mr. Regg's request for the submittal of a variance,well performance data and the valve settings immediately as well as performing a successful field test of the K SSSV. However, our understanding was that Step 15 showing we were going to perform a no-flow test or install a K SSSV was sufficient. We look forward to discussing this matter further with you and your staff at your convenience. Sincerely, liti /. Leland Tate COO Miller Energy Resources, Inc. 1 • S Regg, James B (DOA) From: Regg, James B (DOA) � I Sent: Monday, November 02, 2015 2:58 PM \s� �l t 12,1 ice, To: David Kumar(David.Kumar@cookinlet.net); 'leland.tate@cookinlet.net Subject: Badami B1-11A K-Valve Sundry Status The sundry application for the K-valve in Badami B1-11A (PTD 1980340) is still working its way through our approval process. I understand the well was shut in after you received the notice of violation. It is ok to place B1-11A back in production. 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(caalaska.gov. 1 ti OF Tk • • I 7777 m THE STATE Alaska Oil and Gas ��,,; �� of T cKA Conservation Commission llif#x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 '4LAS' Fax: 907.276.7542 www.aogcc.alaska.gov October 28, 2015 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 0640 0006 0779 5999 Mr. Leeland Tate Interim COO Miller Energy Resources, Inc. 601 W. 5`h Avenue STE 310 Anchorage,AK 99501 Re: Docket Number: OTH-15-027 Badami B1-11A (PTD 1980340) Notice of Violation Unauthorized Installation of an Alternate Subsurface Safety Valve Dear Mr. Tate: Alaska Oil and Gas Conservation Commission (AOGCC) requires the installation of a surface controlled subsurface safety valve in certain wells as described in 20 AAC 25.265(d). The Savant Alaska LLC (Savant)-operated wells within the Badami field located on the North Slope of Alaska fall into the category of wells requiring a surface controlled subsurface safety valve.' Badami operations personnel notified AOGCC on October 19, 2015 that an alternate type of subsurface safety valve was installed in Badami well B1-11A on October 17, 2015.2 Installation of a subsurface safety valve other than a surface controlled valve without prior AOGCC approval is a violation of State regulations. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a description of what has been or will been done in the future to prevent its recurrence at Miller- managed wells in Alaska. Corrective actions will be subject to AOGCC approval. Savant relies on Sundry 311-109 dated April 5, 2011 as AOGCC authorization for use of a subsurface controlled subsurface safety valve. Savant also references a no-flow determination for Badami B1-11A granted by AOGCC on October 5, 2012. The no flow determination Miller Energy Resources,Inc. is manager of Savant Alaska LLC 2 The alternate subsurface safety valve was referred to as a"K-valve". This subsurface controlled subsurface safety valve is normally open and remains in the open position to allow production to flow to surface. If well control is compromised,the valve is actuated closed by the characteristics of the well instead of hydraulic,electrical, mechanical or other controls from the surface. • Docket Number:OTH-15-027• Unauthorized Installation of SSCSV October 28,2015 Page 2 of 2 authorizing removal of the subsurface controlled subsurface safety valve from the well was conditional: The subsurface safety valve must be returned to service if Badami BI-IIA 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. Because the correct trip pressure for closing a subsurface controlled subsurface safety valve is dependent on current well-specific data, elimination of the subsurface safety valve in Badami B1-11A in 2012 effectively invalidated Sundry 311-109. As a result, Savant incorrectly assumed the original approval for the alternate subsurface safety valve remained in effect. When Savant added perforations to Badami B1-11A on September 30, 2015, it was required to either place a surface controlled subsurface safety valve in or obtain advance approval for a subsurface controlled subsurface safety valve. Savant did not do so. The AOGCC reserves the right to pursue enforcement action in connection with the installation and operation of an alternate subsurface controlled subsurface safety valve in Badami B1-11A as provided by 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, '‘Y-ef ot° -(A44-- -- Cathy P. oerster Chair, Commissioner cc: D. Kumar, Savant RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. U.S. Postal ServiceTM CERTIFIED MAIL° RECEIPT off" Domestic Mail Only E' For delivery information,visit our website at www.usps.com''. cr N. Certified Mail Fee N $ CO Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(hardcopy) $ .--1:1 0 Return Receipt(electronic) $ Postmark CI ❑Certified Mail Restricted Delivery $ Here ❑Adult Signature Required $ 0 Mutt Signature Restricted Delivery$ ID Postage $ --0 Total Postage and Fees 6 Mr. Leeland Tate I.I Sent To Interim COO a ' Q treetandApt.No.,or PO Box No Miller Energy Resources, Inc. r- a 601 W.5th Ave.,Ste. 310 -. City,State,ZIP+4 Anchorage,AK 99501 PS Form 3800,April 2015 PSN 71 SLIDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY • Complete items 1,2,and 3. A. Signature ■ Print your name and address on the reverse X L�Agent so that we can return the card to you. /"`��� 0 Addressee • Attach this card to the back of the mailpiece, B.... eceived by(Printed Name) C. Dat of Delivery or on the front if space permits. I (Of �l Q;fr 11/21/5 1. j D. Is delivery address different from item 1? 0 Yes If YES,enter delivery address below: ❑ No Ir. Leeland Tate krim COO Energy Resources, Inc. .5th Ave.,Ste.310 A orage,AK 99501 I! 3. Service Type ❑Priority Mail Express® I{ 1 1'I' I!I III II II I II I II II i II I III Fill IIII I I 0 Restricted Adult Signature ❑Registered Mail Adult Signature Restricted Delivery 0 Registered Mail R r4'Certified Mail® Delivery 9590 9401 0057 5071 0132 08 0 Certified Mail Restricted Delivery 1F'ieturn Receipt for 0 Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery 0 Signature Confirmation'. Lured Mail 0 Signature Confirmation 7 015 0640 0006 0779 5999 ;ured Mail Restricted Delivery Restricted Delivery PS Form 3811,April 2015 PSN 7530-02-000-9053 Domestic Return Receipt (1-114 • • P f rgpi L', Regg, James B (DOA) From: Conrad Perry <Conrad.Perry@cookinlet.net> ���( 1O\ Sent: Wednesday, October 21, 2015 4:53 PM To: Regg,James B (DOA) Cc: Carlisle, Samantha J (DOA); Schwartz, Guy L (DOA); Loepp, Victoria T (DOA); Roby, David S (DOA);Wayne Kuykendall; Leland Tate; David Kumar; Stephen Ratcliff Subject: Badami/Savant AOGCC Point Contacts/PTD 198-340 Attachments: Badami AOGCC Point Contacts.pdf Jim, David Kumar should have the K valve set points and well data to you by early tomorrow afternoon for Badami B-11A. I apologize for the delay, but the set process is more complicated than we had envisaged. FYI, the current K valve in the well is set at 180 psi. I have attached a letter we are sending to Cathy concerning the Badami point contacts for AOGCC. Mr. Leland Tate has assigned David Kumar for production related items and myself for well work. If you desire only a single point of contact it will be me, with David as an alternate. conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage, AK 99501 (907)433-3816—Office (907) 727-7404-Cell (907) 344-0584- Home (907) 260-5356-Cabin conrad.perry@cookinlet.net CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential.If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.433.3816 and then delete this message and its attachments from your computer. 1 • • Regg, James B (DOA) From: Steve Sage <Steve.Sage@savantalaska.com> Sent: Wednesday, October 21, 2015 11:42 AM Key t bk-t(i 6- To: Regg,James B (DOA) Cc: Wayne Kuykendall; David Kumar; Daniel Clark Subject: RE: SVS BAD 10-17-15 Attachments: B1-11A Fm 10-404 - Report of Sundry Well Ops #311-109 -Install K-Valve ....pdf; B1-11A Sundry Approvals# 311-109 K-Valve Installation 5Apr2011.pdf; B1-11A No- Flow Varification - Passed - 10-05-2012.pdf Mr. Regg, Attached is the original Report of Sundry, original Sundry Approval and original No-Flow Verification along with the current surface conditions.The Well conditions have not changed from the original Sundry application. Original conditions at the k-valve per the flowing temperature/pressure survey completed on 3/30/2011 (attached in the Report of Sundry packet) • Pressure—400.75 psi @ 2212' MD • Temperature—39.54 degF @ 2212' MD • Original k-valve dome pressure set @ 333 psi Current surface conditions: • Calculated pressure at the k-valve—408 psi @ 2212' MD • Estimated temperature at the k-valve—40 degF @ 2212' MD • Flowing Temperature—70 degF • Flowing Pressure—195 psi • Flow Rate—263 BOPD • Oil Density- .9187 g cm^3 • Produced Gas Density- .687 g/cmn 3 • TVD-2142' • K-valve dome pressure set @ 180 psi Regards, Steve Sage Operations Superintendent NS Office: 907.659.1322 Cell: 406.546.4931 Harmony: 4015 ALT:John Fairchild 1 • • SAVANT ALASKA From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, October 20, 2015 9:29 AM To: Steve Sage Subject: RE: SVS BAD 10-17-15 Installation of a K-valve is a variance from the SSSV regulatory provision (surface controlled subsurface safety valve)that requires approval before installation. Removal of the K-valve invalidated the approval granted in 2011. Refer to guidance bulletin 10-004 for info that was required to be submitted for AOGCC review and approval. Has any of the info required for approval changed since 2011—same valve; gross fluid rate; flowing temp, flowing pressure and temperature, both at the valve at the wellhead and at the valve depth; dome charge? 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: Steve Sage [mailto:Steve.Sage@savantalaska.com] Sent: Tuesday, October 20, 2015 6:53 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Wayne Kuykendall; David Kumar Subject: RE: SVS BAD 10-17-15 Mr. James Regg B1-11A was approved for a K-Valve on April 5, 2011, Sundry Number: 311-109 and shortly after was approved as a no-flow on October 5, 2012. Regards, Steve Steve Sage Operations Superintendent NS Office: 907.659.1322 Cell:406.546.4931 2 • • Harmony:4015 ALT: John Fairchild SAVANT ALASKA From: Regg, James B (DOA) [mailto:jim.req @alaska.gov] Sent: Monday, October 19, 2015 7:45 PM To: Steve Sage; Brooks, Phoebe L(DOA) Cc: Wayne Kuykendall; David Kumar Subject: RE: SVS BAD 10-17-15 Did you apply for approval to install a K-valve? Sent from my Samsung Galaxy smartphone. Original message From: Steve Sage <Steve.Sage a savantalaska.com> Date: 10/19/2015 5:12 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, "Brooks, Phoebe L (DOA)" <phoebe.bro oks @alaska.gov> Cc: Wayne Kuykendall <Wayne.Kuykendall@savantalaska.com>, David Kumar <David.Kumar@CookInlet.net> Subject: SVS BAD 10-17-15 Original message From: Steve Sage <Steve.Sage@savantalaska.com> Date: 10/19/2015 5:12 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, "Brooks, Phoebe L (DOA)" <phoebe.brooks(alaska.gov> Cc: Wayne Kuykendall <Wayne.Kuykendall@savantalaska.com>, David Kumar <David.Kumar@CookInlet.net> Subject: SVS BAD 10-17-15 Mr. James Regg, On September 30, 2015 Savant Alaska completed adding perforations to well B1-11A; Sundry Number 315- 511, prior to Adding Perforations B1-11A was witnessed and approved as a no-flow Well on October 5, 2012. 3 . • • In order for Savant's B1-11A well to remain compliant with regulation 20 AAC 25.265, a SSSV (K-Valve) was installed on October 17th, 2015 and performance tested on October 18th, 2015. Savant intends to notify AOGCC and perform another witnessed no-flow test on B1-11A in November when Badami's 90 day SVS testing cycle is due. Regards, Steve Steve Sage Operations Superintendent NS Office: 907.659.1322 Cell:406.546.4931 Harmony: 4015 ALT:John Fairchild SAVANT ALASKA 4 • • Regg, James B (DOA) From: Regg, James B (DOA) ejet (0'1(15 Sent: Wednesday, October 21, 2015 12:25 PM To: 'Steve Sage'; Wayne Kuykendall; Daniel Clark Cc: David Kumar; Schwartz, Guy L (DOA) Subject: RE: SVS BAD 10-17-15 Badami B1-11A PTD 1980340 What is the timing for submittal of the Sundry application (to authorize the 10/17/15 installation of a K-valve in Badami B1-11A) mentioned in yesterday's phone conversation with Conrad Perry? We need a Savant contact for correspondence. 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 orjim.regg@alaska.gov. From: Steve Sage [mailto:Steve.Sage@savantalaska.com] Sent: Wednesday, October 21, 2015 11:42 AM To: Regg, James B (DOA) Cc: Wayne Kuykendall; David Kumar; Daniel Clark Subject: RE: SVS BAD 10-17-15 Mr. Regg, Attached is the original Report of Sundry, original Sundry Approval and original No-Flow Verification along with the current surface conditions.The Well conditions have not changed from the original Sundry application. Original conditions at the k-valve per the flowing temperature/pressure survey completed on 3/30/2011 (attached in the Report of Sundry packet) • Pressure—400.75 psi @ 2212' MD • Temperature—39.54 degF @ 2212' MD • Original k-valve dome pressure set @ 333 psi Current surface conditions: • Calculated pressure at the k-valve-408 psi @ 2212' MD • Estimated temperature at the k-valve—40 degF @ 2212' MD 1 • • • Flowing Temperature—70 degF • Flowing Pressure—195 psi • Flow Rate—263 BOPD • Oil Density- .9187 g/cm^3 • Produced Gas Density- .687 g/cm^3 • TVD-2142' • K-valve dome pressure set @ 180 psi Regards, Steve Sage Operations Superintendent NS Office: 907.659.1322 Cell: 406.546.4931 Harmony: 4015 ALT: John Fairchild SAVANT ALASKA From: Regg, James B (DOA) [mailto:jim.regg@ alaska.gov] Sent: Tuesday, October 20, 2015 9:29 AM To: Steve Sage Subject: RE: SVS BAD 10-17-15 Installation of a K-valve is a variance from the SSSV regulatory provision (surface controlled subsurface safety valve)that requires approval before installation. Removal of the K-valve invalidated the approval granted in 2011. Refer to guidance bulletin 10-004 for info that was required to be submitted for AOGCC review and approval. Has any of the info required for approval changed since 2011—same valve; gross fluid rate; flowing temp,flowing pressure and temperature, both at the valve at the wellhead and at the valve depth; dome charge? 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: Steve Sage [mailto:Steve.Sage@savantalaska.com] Sent: Tuesday, October 20, 2015 6:53 AM 2 • ' To: Regg, James B (DOA); Brooks, Phoebe L (DOA) • Cc: Wayne Kuykendall; David Kumar Subject: RE: SVS BAD 10-17-15 Mr. James Regg B1-11A was approved for a K-Valve on April 5, 2011, Sundry Number: 311-109 and shortly after was approved as a no-flow on October 5, 2012. Regards, Steve Steve Sage Operations Superintendent NS Office: 907.659.1322 Cell: 406.546.4931 Harmony: 4015 ALT: John Fairchild SAVANT ALASKA From: Regg, James B (DOA) [mailto:jim.reggC@alaska.gov] Sent: Monday, October 19, 2015 7:45 PM To: Steve Sage; Brooks, Phoebe L (DOA) Cc: Wayne Kuykendall; David Kumar Subject: RE: SVS BAD 10-17-15 Did you apply for approval to install a K-valve? Sent from my Samsung Galaxy smartphone. Original message From: Steve Sage <Steve.Sage asavantalaska.com> Date: 10/19/2015 5:12 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, "Brooks, Phoebe L (DOA)" <phoebe.brooksa,alaska.gov> Cc: Wayne Kuykendall <Wayne.Kuykendall cr,savantalaska.com>, David Kumar <David.Kumar@CookInlet.net> Subject: SVS BAD 10-17-15 3 • • Original message From: Steve Sage <Steve.Sage@savantalaska.com> Date: 10/19/2015 5:12 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, "Brooks, Phoebe L (DOA)" <phoebe.brooks@a alaska.gov> Cc: Wayne Kuykendall <Wayne.KuykendallAsavantalaska.com>, David Kumar <David.Kumar@Cooklnlet.net> Subject: SVS BAD 10-17-15 9b1, Mr. James Regg, On September 30, 2015 Savant Alaska completed adding perforations to well B1-11A; Sundry Number 315- 511, prior to Adding Perforations B1-11A was witnessed and approved as a no-flow Well on October 5, 2012. In order for Savant's B1-11A well to remain compliant with regulation 20 AAC 25.265, a SSSV (K-Valve) was installed on October 17th, 2015 and performance tested on October 18th, 2015. Savant intends to notify AOGCC and perform another witnessed no-flow test on B1-11 A in November when Badami's 90 day SVS testing cycle is due. Regards, Steve Steve Sage Operations Superintendent NS Office: 907.659.1322 4 •• Cell: 406.546.4931 Harmony: 4015 ALT:John Fairchild SAVANT ALASKA 5 • • Regg, James B (DOA) From: Regg,James B (DOA) Sent: Tuesday, October 20, 2015 9:29 AM To: 'Steve Sage' Subject: RE: SVS BAD 10-17-15 Installation of a K-valve is a variance from the SSSV regulatory provision (surface controlled subsurface safety valve)that requires approval before installation. Removal of the K-valve invalidated the approval granted in 2011. Refer to guidance bulletin 10-004 for info that was required to be submitted for AOGCC review and approval. Has any of the info required for approval changed since 2011—same valve; gross fluid rate; flowing temp,flowing pressure and temperature, both at the valve at the wellhead and at the valve depth; dome charge? 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 iim.regg@alaska.gov. From: Steve Sage [mailto:Steve.Sage@ savantalaska.com] Sent: Tuesday, October 20, 2015 6:53 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Wayne Kuykendall; David Kumar Subject: RE: SVS BAD 10-17-15 Mr. James Regg B1-11A was approved for a K-Valve on April 5, 2011, Sundry Number: 311-109 and shortly after was approved as a no-flow on October 5, 2012. Regards, Steve Steve Sage Operations Superintendent NS Office: 907.659.1322 Cell: 406.546.4931 Harmony:4015 ALT:John Fairchild 1 • • SAVANT ALASKA From: Regg, James B (DOA) [mailto:jim.reci alaska.gov] Sent: Monday, October 19, 2015 7:45 PM To: Steve Sage; Brooks, Phoebe L (DOA) Cc: Wayne Kuykendall; David Kumar Subject: RE: SVS BAD 10-17-15 Did you apply for approval to install a K-valve? Sent from my Samsung Galaxy smartplione Original message From: Steve Sage <Steve.Sage@savantalaska.com> Date: 10/19/2015 5:12 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, "Brooks, Phoebe L (DOA)" <phoebe.brooks@alaska.gov> Cc: Wayne Kuykendall <Wayne.Kuykendall@savantalaska.com>, David Kumar <David.Kumar@Cooklnlet.net> Subject: SVS BAD 10-17-15 Original message From: Steve Sage <Steve.Sage@savantalaska.com> Date: 10/19/2015 5:12 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg(&,,alaska.gov>, "Brooks, Phoebe L (DOA)" <phoebe.brooksnalaska.gov> Cc: Wayne Kuykendall <Wayne.Kuykendall@savantalaska.com>, David Kumar <David.Kumar@C ooklnl et.net> Subject: SVS BAD 10-17-15 Mr. James Regg, On September 30, 2015 Savant Alaska completed adding perforations to well B1-11A; Sundry Number 315- 511, prior to Adding Perforations B1-11A was witnessed and approved as a no-flow Well on October 5, 2012. 2 • In order for Savant's B1-11A well remain compliant with regulation 200AC 25.265, a SSSV (K-Valve) was installed on October 17th, 2015 and performance tested on October 18th, 2015. Savant intends to notify AOGCC and perform another witnessed no-flow test on BI-11A in November when Badami's 90 day SVS testing cycle is due. Regards, Steve Steve Sage Operations Superintendent NS Office: 907.659.1322 Cell:406.546.4931 Harmony: 4015 ALT:John Fairchild SAVANT ALASKA 3 OF TfJ� yiyP,��I y7,- 0 THE STATE Alaska Oil and Gas A6-4.3 -- M o A j\ J(j\ Conservation Commission i - 333 West Seventh Avenue kvtlf7`t-=,, Anchoroge, Alaska 99501-3572 Op ,� GOVERNOR BILL WALKER Main: 907.279.1433 ALAS Fax' 907.276 7542 www.aogcc.alaska goy Conrad Perry Drilling Manager Savant Alaska, LLC 601 W. 5th Ave., Ste. 310 +, 03'1 Anchorage,AK 99501 �� Re: Badami Field,Badami Oil Pool, B1-1 1 A Sundry Number: 315-511 Dear Mr. Perry: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this day of August, 2015 Encl. RBDMS SI 0 4 2015 • • STATE OF ALASKA RECEIVEL AUG 2 1 2 015 ALASKA OIL AND GAS CONSERVATION COMMISSION CQ-5 Cri/W 15 APPLICATION FOR SUNDRY APPROVALS AOGCL, 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations LI Fracture Stimulate 121 Pull Tubing E] Operations shutdown El Suspend Li Perforate [1] • Other Stimulate Li Alter Casing E Change Approved Program LI Plug for Redrill Li Perforate New Pool CI Repair Well 0 Re-enter Susp Well [11 Other: LI 2.Operator Name: 4.Current Well Class. 5. Permit to Drill Number: Savant Alaska LLC Exploratory 0 Development LI .. 198-034 47 3.Address: 6.API Number: Stratigraphic LI Service Li 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 50-029-22829-01 , 7.If perforating: (1, r, yr,z.,./1 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC-25:067 /3I?4,--,''c 81-11A - Will planned perforations require a spacing exception? Yes 0 No E1 9.Property Designation(Lease Number): 10.Field/Pool(s): At-,L.— 367011 Badami Field, Badami Oil Pool 11. AN',2,i-t;PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft) Plugs(measured): Junk(measured): 13,375' A 10,475 13,149' 10,307' ',,. Fish(4113231 Casing Length Size MD ND Burst Collapse Structural Conductor 7420" 110' 110' 520 Surface 5,025' 9 5/8" 5,059' 4,534' 5750 3090 Intermediate 10573 7" 10,606' 8,434' 11220 8510 Production Liner 2,944' 4 1/2" 13,375' 10,475' 7780 6350 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): ____ 12606- 13246 9925- 10379 45' L80 ...._ 10,324' Packers and SSSV Type: 7"x 4 1/2"HES TNT Pkr/no SSSV Packers and SSSV MD(ft)and TVD(ft): Pkr @ 10274/8152 TVD 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch LI Exploratory Li Stratigraphic LI Development LT Service 0 14. Estimated Date for 21-Aug-15 15.Well Status after proposed work: Commencing Operations. OIL Li- WINJ Li WDSPL D Suspended [1] 16.Verbal Approval: Date: GAS c] WAG LI GSTOR [1] SPLUG CI Commission Representative: GINJ LI Op Shutdown 0 Abandoned EI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stephen Ratcliff -,, Email steptiensatcliff( cookinletnet Printed Name conrad perry Title Drilling Manager Signature („,^' ,,./..„,/ Phr),,,--'907-727-7404 Date July 30th,2015 COMMISSION USE ONLY Conditions of approval: Notify Co is on so that'. (resentative may witness (7‘ Sundry Number: 5 tk Plug Integrity [1] BOP Test 0 Mechanical Integrity Test 0 Location Clearance EI Other: Spacing Exception Required? Yes CI] No [21 Subsequent Form Required: / ) -ioti APPROVED BY Approved by. ' ' • ., COMMISSIONER THE COMMISSION Date: ,--- 2,1, i 4' Submit Form and fteN3/40s ettpl I% keRiti-go IftlAtfor 12 m ths from the date of approval. Attachments in pruplicate • • 1. WELL NAME - Badami B1-11A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing. Current Perforations MD TVD 13,206' - 13,246' 10,295' - 10,323' 12,676' - 12746' 9,917' - 9,969' 12,606' - 12,666' 9,870' - 9,917' Scope of Work: • Rig up eLine. Test Lubricator to 3000psi • Perforate selected zones sequentially. o If 1 11/16" guns are ineffective or won't go down, pull POGLM sleeves • Re-Run POGLM Sleeves if pulled. • Rig down. Flow well General Well information: Reservoir Pressure /TVD: 7225 psi @ 10,340" TVD (.70 psi/ft) MASP: 4846 psi (Half oil/Half gas) 7225 psi - (5170' well with .35 psi/ft oil) -( 5170' with .1 psi/ft gas gradient) 4846 psi = 7225psi - 1809psi -570psi Wellhead Type/Pressure Rating: 11" Multibowl 5K Wellhead Well Type: Oil Well Estimated Start Date: September 15th, 2015 CIE Drilling Manager: CIE Sr. Drilling Engineer: CIE Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-9738 (907)433-3822 conrad.perry@Cooklnlet.net Stephen.Ratcliff@Cooklnlet.net David.Kumar@CookInlet.net 3 • • Program 1. Clean up well bore with slick line/diesel washes. 2. Shut well in. 3. Rig up eLine. Test lubricator to 5000 psi. 4. Make dummy run with 1 11/16" sinker bar. Note max angle through perfs is 48 degrees 5. Perforate with 1 11/16" strip guns from 13,147' to 13,206'. Approximate .25" entry hole and 19" of API penetration. 6. Rig down eLine and put well to production to determine small gun effectiveness*. 7. If production increase is seen, continue perforating entire program a. 13,147' - 13,206' 59' A5 b. 13,062' - 13,140' 78' A5 c. 12,758' - 12,793' 35' F5 8. If no production increase, rig up Slick line and test lubricator to 5000 psi 9. Recover POGLM from 4000' and from 10,155'. 10. Make dummy run with 3 1/8" drift. Note max angle through perfs is 48 degrees 11. Rig down slick line. Rig up eLine and Test Lubricator to 5000 psi. 12. Re-perforate with 3 1/8" casing guns from 13,147' to 13,206'. 13. If pressure increase is seen, continue perforating entire program a. 13,062' - 13,140' 78' A5 b. 12,758' - 12,793' 35' F5 14. Re-install GOGLMs at 10,155' and 4,000'. Perform FIT on annulus. 15. Perform no flow test or install K SSSV. *The above stepped program is designed to minimize risk and production shut-in. The POGLMs do not have to be touched if the 1 11/16"guns are effective. Their effectiveness is tested over the best 60'interval in the proposed pelf adds. There are three possible outcomes with the small guns. One is success, two insufficient penetration, and three sufficient penetration, but no reservoir. 4 • • Current Badami B1-11A Schematic Dri Floor to C o axi Level 53.9 Tree 4 1/16*5000 PSI CIW 013; 1D Wcight Length 'MD TND Omni Level to Sea Level 18.6' Wellhead 13 5/8710000,_' MC ice inch Lin/ DF SS Note:BPV removed 3122/10 4-1/2"12.6#L-80 NSCT MOD.0152 bpf 4.500 3.958 10324 10324 8221 2° 1 1< 4-1/2"HES X NIP,ID(SSSV Pennasmtly Rem°vd Sept.20 4.500 3.873 2207 2142 4-1/2"HES DWP 4.500 1.910" 3990 3738 430 �' 154, Hobs a Tt bieg fix Gas I2;1 4000 3747 #2 GIM(Pt7G1.M 5,}Dome Valve,IlK Laic*16 P 4000 3747 45° 4 I < 13-3/8"CSG,68#,L-80 BTC 13380 12.415 5059 4485 44° - Holes in ltbirg for('Gas Lill 10155 8103 1l1GIM(PC?6IM[3)SI)Valve,BIC liteby20Part 10155 8103 44* X X 7"X 4-1/2"MN TNT?KR 7.500 3.850 10274 8183 4 4-1/2"XNippb 4.500 3.813 10291 8196 ee 4+ 4-1/2"XN Nipple 4.500 3.725 10312 8213 2-3/8"X Red iig Nip b 2.380 1.875 10316 8215 Note:8318"XX Hog Removed 3/23/10 2.380 10316 8215 FIMD1TNot Loggedd 4-1/2"WL EG 4.500 3.958 10324 8220 -- 7"X4-1/2",INRHGRPKR 420 • Top of 4-1/2"Liner 12.6#,L-80 BCT MOD.0152 bpf 4.500 3.958 10430 8376 7"LNR 29#P11013TC �E 7.000 6.184 10605 8430 49° MaXirsniI)cv mAride 12251 9635 12606'-12666'MD;9870'-99171VDSS 10/31/98 12676'-12746'MD;9917-9969'TVOSS 10/31/98 FRAC') 13206'-13246'MD;10295'-10323'TVDSS 8/8/98 383833 PBTD 13288 10356 No. Rev.by Curie It l 11.1 I DDW Sidetrack(81-11A)2/9/08 Location action Baden'Halt 2 MAS Add POGIAMS 4/1/02 API No.50029-22829-01 3 SWC Set XX Plug @ 10312 9/3/07 PLL)No.198-0340 4 R Beebe Updates 9/9/12 'IBC 8,T9N,R20E,1426'FNL&156'FE! 5 Cr 7-30-15 Removed Cbsed rote capetffiLasted • July 30,2015 S"AVANT 5 ALASI'(A el.‘ w � ����y� THE STATE Oil and °ALASKA Gas ALASKA Conservation Commission GOVERNOR SEAN PARNELL O �, 333 West Seventh Avenue ALAS Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 October 5, 2012 Mr. Erik Opstad General Manager, Alaska Operations Savant Alaska, LLC P.O. Box 112212 Anchorage, AK 99511 RE: No-Flow Verification Badami Unit B1-11A PTD 1980340 Dear Mr. Opstad: On September 4, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Badami Unit well B1-11A located on Alaska's North Slope. The well is operated by Savant Alaska, LLC (Savant). 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 in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the well was shut in and proper test equipment— as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to Badami B1-11A. The no-flow test consisted of a series of flow and shut in periods. The maximum flow rate measured was 180 standard cubic feet per hour (SCFH) quickly falling off to 40 SCFH; the flowing pressure ranged from a maximum 1.5 psi to 0.2 psi. During the shut-in monitoring periods, the maximum measured pressure was 1.8 psi. There was no liquid production to surface during the test. The AOGCC Inspector granted Savant verbal approval to place B1-11A back on production without a subsurface safety valve based on the successful no flow test. The subsurface safety valve must be returned to service if Badami B1-11A 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, b 1 \e17 James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors II II voFrift �w�l%%i ,v THE STATE Alaska Oil and Gas ��,0,. OJ LA Conservation Commission s }...1-_-1-4_,_-_,- ..12 _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Illi i,- Main: 907.279.1433 94'ALAS11J' Fax: 907.276.7542 www.aogcc.alaska.gov David Kumar JAN 1 9 2016 Production Manager Savant Alaska, LLC i O 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: Badami Field, Badami Oil Pool, B1-11A Sundry Number: 315-664 Dear Mr. Kumar: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, allA Cathy P. Foerster Chair DATED this 3 day of November, 2015 End. C/ RBDMS RBDMS NOV 0 9 2015 • RECEIVED STATE OF ALASKA OCT 2 2 2015 , ALASKA OIL AND GAS CONSERVATION COMMISSION ///..3 //j APPLICATION FOR SUNDRY APPROVALS AOGr " 20 AAC 25.280 1.Type of Request: Abandonu Plug Perforations I=1 Fracture Stimulate IJ Pull Tubing u Operations shutdownll Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill—IPerforate New Pool B Repair Well Re-enter Susp Well Other:K-Valve • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Savant Alaska,LLC Exploratory E Development . 198-034 • 3.Address. Stratigraphic Service 6.API Number: 601 W.5th Avenue,Suite 310.Anchorage,AK 99501 50-029-22829-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.0 402A B1-11A • Will planned pe-it ations require a spacing exception? Yes IJ No IXI 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 367011 • Badami Field Badami 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): 13,375 10,475 13,149 10,307 N/A Fish@13,231' Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 110' 110' 1,530 psi 520 psi Surface 5,025' 9-5/8" 5,059' 4,534' 5,750 psi 3,090 psi Intermediate 10,573' 7" 10,606' 8,484' 11,220 psi 8,510 psi Production Liner 2,944' 4-1/2" 10,430'-13,375' 8,354'-10,475' 7,780 psi 6,350 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6 Intervals 12,606'to 13,246' 9,870'to 10,323' 4-1/2"12.6# L-80 10,324' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 4-1/2"HES TNT Packer K-Valve as Subsurface Control Packer at 10,274'MD(8,152'TVD) K-Valve at 2,212'MD(2,212'TVD) 12.Attachments: Description Summary of Proposal ® 13.Well Class after proposed work: • Detailed Operations Program W BOP Sketch I I Exploratory I I StratigraphicI I Development IXI Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations. K-Valve was installed on Oct 17th,2015 OIL ® • WINJ WDSPL Suspended 1=116.Verbal Approval: Date: GAS 1=1 WAG u GSTOR SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Kumar Email david.kumarcookinlet.com Printed Name David KumarTitle Production Manager Signature �/ Phone Date COMMISSION USE ONLY Conditions of approval Not Commission so that a representative may witness Sundry Number: 315 - 4cQi"E Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 46- 1 u.71--;5 s"cts-ce € .74-1, ila (---IWI\e-s-....< .)/ , Spacing Exception Required? Yes ❑ NoEr/ Subsequent Form Required: / 0— 41 6 t f U APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: //, 3 — f,� /e —3//S" !r t Submit Form and Form 10-403 Revised 5/2015 pproved application is valid for 12 months from the date of approval. Attachments in Duplicate hRBDMSUV u 9 2015 / �c °��" ORIGINAL s (0wZs.„--- • RECEIVED Cook Inlet Energy 2 2 2015 October 21, 2015 AOGCC Mr. Jim Regg, Supervisor, Inspections Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Subject: Sundry Requesting use of K-Valve on B1-11A at Badami Dear Mr. Regg, Savant Alaska, LLC is requesting a variance to use a K-Valve in B1-11A as a method of subsurface safety as per the attached Sundry request. Savant Alaska previously requested a variance to use a K-Valve on this well and was granted permission to do so on April 2011. This variance was superseded by demonstration of a no flow test to the Commission on Sep 2012, which rescinded the use of the K-Valve for the above mentioned well. As per a recently approved Sundry (315-511) by the Commission, 3 sets of perforations were added to the well, with operations ending September 30, 2015. Following clean up operations the K-Valve was reinstalled on October 17, 2015, anticipating changes in reservoir conditions following the addition of those perforations. Most of the flow, pressure and temperature data gathering for the variance was only possible only after the installation of the K-Valve and is presented to the Commission along with this Sundry. Following the installation, it has been noted that the flowing pressure and temperature conditions haven't changed significantly since the last time the K- Valve was used. Savant Alaska is requesting the Commission to approve use of the K-Valve and is submitting the following documents 1. Application for Sundry Approval 2. Current Wellbore Diagram 3. Previous and Current conditions at which the K-Valve is Operating 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745 Main 1(907)334-6735 Fax • • 4. Installation Procedure for the K-Valve 5. B1-11A SVS Test Report for the K-Valve conducted on 10/17/15 Savant Alaska is also willing to demonstrate to the Commission a no flow test in event the use of the K-Valve is not approved. If any further information is needed, please don't hesitate to contact me at (907) 433-3822 or at david.kumar@cookinlet.net Sincerely, \ 01 ,01' L—vic\-?t, Prodon Manager Cook Inlet Energy 601 W.5`h Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745 Main 1(907)334-6735 Fax • B 1 - 11A ! Drill Floor to Ground Level 53.9' Tree 41/16" 5000 PSI CIW OD 1D Weight Length MD TVD Ground Level to Sea Level 18.6' Wellhead 13 5/8"/10000 psi/FMC inch inch Lbs/ft ft DO SS Note:BPV removed 3/22/10 ' < 4-1/2"12.6#L-80 NSCT MOD.0152 bpf 4.500 3.958 10324 10324 8221 2' I: 4-1/2"HES X NIP,ID(K-Valve installed on 10/17/15 at 2,112') 4.500 3.813 2207 2142 4-1/2"HES DWP 4.500 1.910" , 3990 3738 43" Holes in Tubing for Gas Lift 4000 3747 #2 GLM(POGLMS)Dome Valve,BK Latch,16 Port 4006 3747 45" 13-3/8"CSG,68#,L-80 BTC 13.380 12.415 5059 4485 44° 11 Holes in Tubing for Gas Lift 10155 8103 #1 GLM(POGLMS)SO Valve,BK Latch,20 Port 10155 8103 44° R X 7"X 4-1/2"HES TNT PKR 7.500 3.850 10274 8183 4-1/2" X Nipple 4.500 3.813 10291 8196 4-1/2"XN Nipple 4.500 3.725 10312 8213 2-3/8"X Reducing Nipple 2.380 1.875 10316 8215 Note:2-3/8"XX Plug Removed 3/23/10 2.380 10316 8215 / s ELMD TT Not Logged 4-1/2"WLEG 4.500 3.958 10324 8220 7"X 4-1/2",LNR HGR PKR 42" • vi 4___________— Top of4-1/2"Liner 12.64,L-80 BCT MOD.0152 bpf 4.500 3.958 10430 8376 A k*----- 7"LNR 29#P110 BTC 7.000 6.184 10605 8430 Maximum Deviation Angle 12251 9635 D 12606'-12666'MD;9870'-9917'TVDSS 10/31/98 12676'-12746'MD;9917'-9969'TVDSS 10/31/98 D 12758'-12793'MD;9975'-10031'TVDSS 9/27/15 0 FRAC'D 13062'-13140'MD;10189'-10247'TVDSS 9/27/15 13147'-13206'MD;10252'-10295'TVDSS 9/27/15 13206'-13246'MD;10295'-10323'TVDSS 8/8/98 AliiiPBTD 13288 10356 No. Rev.by Comments/Date RI-II_A 1 DDW Sidetrack(B1-11A)2/9/08 Location Correction Badami Unit 2 MAS Add POGLMS 4/1/02 API No.50-029-22829-01 3 SWC Set XX Plug @ 10312 9/3/07 PTO No.198-0340 4 R Berube Updates 9/9/12 SEC 8,T9N,R20E,1426'FNL&156'FEL 5 CJP 7-30-15 Removed Closed note on perfs Lasted Revised: October 20,2015 6 SBR Added perforations from September 2015 Workover 9/27/15 SAVANT ALASKA • Previous and Present Operating Conditions of the K-Valve Previous Conditions 2011 • Pressure - 400.75 psi @ 2212' MD • Temperature - 39.54 degF @ 2212' MD • Original k-valve dome pressure set @ 333 psi Present Conditions 2015 • Calculated pressure at the k-valve- 408 psi @ 2212' MD • Estimated temperature at the k-valve - 40 degF @ 2212' MD • Flowing Temperature- 70 degF • Flowing Pressure - 195 psi • Flow Rate - 263 BOPD • • Oil Density- .9187 g/cm^3 • Produced Gas Density- .687 g/cm^3 • TVD - 2142' • K-valve dome pressure set @ 180 psi (Set due to lower separator pressure —132 psi) • 1.0 SCOPE: Running/Pulling the K-Valve w/XO EQ device—carrier may be included. 2.0 GENERAL INFORMATION: Nipple type and well geometry need to be considered when running a K-valve. This information needs to be recorded for future reference when the K-valve is pulled. If run in a HXO, HRQ or other type Safety Valve Landing Nipple (SVLN), ensure you are finning the correct length 'carrier' between the lock and the equalizing device. The 'carrier' isolates the control and balance line ports, providing pressure integrity across the SVLN. Measure distance from lock to XO-EQ device to select proper prong length. Record data in job log. 3.0 PROCEDURE: Installation A. Drift tubing with appropriate drift size & note tubing pressure. B. Set up X or lock type that fits the nipple profile, and K-Valve assembly to appropriate setting tool (x-line). C. Assemble o-rings on EQ device and fix to X running prong, assemble XO equalizing sub to K-valve. assemble. (EQ device will be off seat). If installing in a SVLN, make-up the carrier as part of this assembly. D. RIH with X-Line running tool in correct position (top nipple- run in controlled position). E. Get P/U weight prior to sitting down in nipple. F. Lightly jar down to seat packing and continue jarring to sheer top pin in running tool. G. Once top pin is sheered, do a pull test min 500# over P/U weight. Proceed to sheer lower pin on running tool by jarring up, which will release running tool from K-Valve assembly, also pulling the XO EQ device on seat. H. POOH, inspect running tool. Retrieval A. Note well status (flowing or shut in) and tubing pressure. B. Drift tubing with appropriate drift size. C. Set up a GS pulling tool with no Dogs and a light pin with XO-EQ prong. Reference installation job log or other document where carrier length (if used) is recorded. D. RIH and sit down on K-Valve assembly. Lightly jar down to knock EQ device off seat and shear GS. Monitor tubing pressure for changes. E. POOH and inspect GS pulling tool for sheared pin and XO-EQ prong for ring from XO-EQ device. F. If pressure change is good and marking on tool look good, take X-EQ prong off GS pulling tool and install dogs. (pump through if equalization is unsure prior to pulling). G. RIH, get P/U weight prior to sitting down on K-Valve assemble, RIH engage lock with GS pulling tool and jar up to release K-Valve assembly. H. POOH and inspect assembly. • .. 0 % ƒ ƒ \ / / / / / } / / \ \• c / \ - >7-7 / \ j \ z Z_ \ £ \ / \ 2" / C \ li:/ ) - z§ � z \/ _ c ®\� \ \ \ \ \ \ /j / oo \ _ a �\ 2 » - / � \4.1 /¥ 2z £ tea O"\ 2 — \ t © y a Et . 4. e c I » Q (--.1 t ) 0- 2 / \ q � » \ ¢ z •E . ( e z - ( / q % jay = C) C%)'cn 4,e ƒ\ / _ $ c 3 \ : % © \ — _ > t a 5 . ■ a E / � � \ ? } 7 \ � Se \ ] _ \ § \ } \ / \ S ( CA \ \ \ . D/D > ccc = = = cccc O• 6o , - 2 / 72 / 20 / / 92 ) 22c = c = - - - m - / 0 = 2 § / 7 4 4 3 2 & 4 4 / - — 2 ) / / 22 - - - - m - - - - m ) o/ ® 2 % /• 2 c) § £ - m < / _ z z z z � Zm2m2209299 . 0. = a = a = _ _ _ _ _ \ • • RECEVED OCT 222015 Miller AOGCC Energy October 22, 2015 SCANNED NOV 0 2 2015 Ms. Cathy Foerster, Chair 3� Alaska Oil and Gas Conservation Commission Cc4C 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Badami B1-36 - Report of Sundry Well Operations Savant Alaska LLC API: 50-029-22829-01 Sundry: 315-511 Dear Ms. Foerster, Miller Energy Resources, Inc., as manager of Savant Alaska, LLC, hereby submits a Report of Sundry Well Operations for Badami B1-11A. This concludes the perforation additions and workover for B1-11A. Included in the Report is the 10-404,Well Schematic, &Workover Reports. If you have any questions,please contact me at 907.727.7404. Sincer , Conrad P Drilling Manager Miller Energy Resources, Inc. As Manager of Savant Alaska, LLC 1 STATE OF ALASKA AlIIPSKA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon — Plug Perforations Fracture Stimulate _ Pull Tubing _ Operations shutdown ,_ Performed: Suspend _ Perforate g Other Stimulate _ Alter Casing — Change Approved Program _ Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: 2.Operator Savant Alaska,LLC 4.Well Class Before Work: 5.Permit to Drill Number Name: Development Exploratory 198-034 3.Address: 601 W.5th Avenue,Suite 310,Anchorage,AK Stratigraphic® Service _6.API Number: 99501 50-029-22829-01 7.Property Designation(Lease Number): ADL 367011 8.Well Name and Number: B1-11A 9.L gs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): OCT 2 2 2015 0 j 5 N/ABadami Field,Badami Oil Pool G 11.Present Well Condition Summary: Total Depth measured 13375 feet Plugs measured - feet true vertical 10475 feet Junk measured 13231 feet Effective Depth measured 13288 feet Packer measured 10274 feet true vertical 10356 feet true vertical 8152 feet Casing Length Size MD TVD Burst Collapse Structural - - Conductor 74 20" 110 110 1530 520 Surface 5025 9 5/8" 5059 4534 5750 3090 Intermediate 10573 7" 10605 8434 11220 8510 Production - - Liner 2944 4 1/2" 13375 10475 7780 6350 Perforation depth Measured depth 12606-13246 feet True Vertical depth 9925-10379 feet Tubing(size,grade,measured and true vertical depth) 4 1/2" L-80 10324 8220 Packers and SSSV(type,measured and true vertical depth) HES-7"X 4-1/2" 10274/8152 No SSSV N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 162 374 0 1,073-Gas Lift 181 Subsequent to operation: 263 332 2 850-Gas Lift 195 14.Attachments(required per 20 AAC 25.070 .071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory n Development® iziService n Stratigraphic after work:Copies of Logs and Surveys Run 16.Well Status Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data D GSTOR nWINJ n WAG GINJ SUSP SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-511 Contact Conrad Perry . Email conrad.perryacookinlet.net :::me Conrad P ry W Title Drilling Manager Phone 907.727.7404 Date 10/22,' 'i vrL 16/2.7-1/5- - ) /07211 f L Form 10-404 Revised 5/2015 RBDMS� UL I I 2015 Submit Original Only • • B1 - 11A Drill Floor to Ground Level 53.9' Tree 4 1/16" 5000 PSI CIW ra', 4:`l > Ground Level to Sea Level 18.6' Wellhead 13 5/8"/10000 psi FMC �� ,, x t l Note:BPV removed 3/22/10 f < 4-1/2"12.6#L-80 NSCT MOD.0152 bpf 4.500 3.958 10324 10324 8221 2° 1 1< 4-1/2"HES X NIP,ID(SSSV Permanently Removd Sept.2012) 4.500 3.813 2207 2142 4 IR 4-1/2"HES DWP 4.500 1.910" 3990 3738 43" 12EAHoles in Tubing for Gas Lift 4000 3747 #2 GLM(POGLMS)Dome Valve,BK Latch,16 Port 4000 3747 45° - <---- 13-3/8"CSG,68#,L-80 BTC 13.380 12.415 5059 4485 44° Holes in Tubing for Gas Lift 10155 8103 #1 GLM(POGLMS)SO Valve,BK Latch,20 Port 10155 8103 44° X X 7"X 4-1/2"HES TNT PKR 7.500 3.850 10274 8183 4-1/2" X Nipple 4.500 3.813 10291 8196 14 4 4-1/2"XN Nipple 4.500 3.725 10312 8213 2-3/8"X Reducing Nipple 2.380 1.875 10316 8215 Note:2-3/8"XX Plug Removed 3/23/10 2.380 10316 8215 ./ ELME)TT Not Logged 4-1/2"WLEG 4.500 3.958 10324 8220 42° .1<-------- 7"X 4-1/2",LNR HGR PKR Top of4-1/2"Liner 12.6#,L-80 BCT MOD.0152 bpf 4.500 3.958 10430 8376 I , 7"LNR 29#P110 BTC 7.000 6.184 10605 8430 49' Maximum Deviation Angle 12251 9635 8 12606'-12666'MD;9870'-9917'TVDSS 10/31/98 12676'-12746'MD;9917'-9969'TVDSS 10/31/98 0 12758'-12793'MD;9975'-10031'TVDSS 9/27/15 6 FRAC'D 13062'-13140'MD;10189'-10247'TVDSS 9/27/15 13147'-13206'MD;10252'-10295'TVDSS 9/27/15 13206'-13246'MD;10295'-10323'TVDSS 8/8/98 AWL PBTD 13288 10356 No. Rev.by Comments/Date 1 DDW Sidetrack(B1-11A)2/9/08 Location Correction Badami Unit 2 MAS Add POGLMS 4/1/02 API No.50-029-22829-01 3 SWC Set XX Plug @ 10312 9/3/07 PTO No.198-0340 4 R Berube Updates 9/9/12 SEC 8,T9N,R20E,1426'FNL&156'FEL 5 CJP 7-30-15 Removed Closed note on perfs Lasted Revised: October 20,2015 6 SBR Added perforations from September 2015 Workover 9/27/15 SAVANT ALASKA • • Savant Alaska,LLC SAANT DAILY DRILLING I WORKOVER REPORT ALASKA DATE 9/28/16 LEASE AND WELL NO Badami-B1-IIA AFE 115006 DAYS 10 NUMBER°T6 Ng ND 13,225' NUMBER OMSIDN6 Are$em Operator) NON m I R T CONTRACTOR AND G NO. B1-11A PERFORATIONS Dailyy 0.0Cumulative POLLARD SL UNIT HSE I I Accidents I I Incidents I I Sp91s I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safely Walk Around Day Safety Walk Around Night Daily Coats DESCRIPTION 1OUFS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS,HEATER ANDTRIPLEX(ULSD) 1r $3.78 5903.25 POLLARD-ELINE SERVICES $33.170.80 (SERVICE CHARGE,PRESS CONTROL,TOOLS,321'GUNS( sow POLLARD-SL SERVICES = 5270 S3240.00 SOA° SO.00 .003 50.00 PERFORATION DETAILS RUNE PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 13,082'-13,07T 15' AS 111(16"0 DEG PHASE STRIP GUN LOST THE BOTTOM GUN AND SWEDGE AFTER FIRING. LOST A LITTLE LINE WEIGHT AFTER FIRINTHEN ADA COUPLE HUNDRED POUND OVER PULL COMING OUT G,OF P05H1TIVERY 2 12,773'-12,793' 20' AS 111116"SNAKE STRIP GUN SLOWLY GAINED 100 PSI ON THE TUBING AFTER THISS SHOT. 3 12,736'-12,773' 15' A5 111(16..0 DEG PHASE STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS TIME LOG TIME DESCRIPTION Sas AM DAILY OPS MEETING AND MORNING TOOLBOX 6:15 AM RIG UP ELINE 7:30 AM PT LUBRICATOR TO 4000 PSI 745 AM RIH WITH 15 1 11/16"0 DEG PHASE STRIP GUN 8:50 AM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 9:25 AM PULL INTO POSITION AND PERFORATE 13,062'-13,077'WITH 15 1 11/36"0 DEG PHASE STRIP GUN.NO PRESSURE CHANGE.POOH 10:00 AM OOH WITH ELINE AND SWAP OVER TO SL AND 811-1WITH BRUSH AND DRIFT LOST BOTTOM GUN,CROSSOVERS AND SWEDGE(OAL=9'1"WITH THE STRIP GUN LOOKING UP 11:45 AM RU ELINE 12:00 PM RIH WITH 20'1 11116"SNAKE STRIP GUN 105 PM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 135 PM PULL INTO POSITION AND PERFORATE 12,758'-12,793'WITH 20'111118"SNAKE STRIP GUN.LOST A LITTLE UNE WEIGHT AFTER FIRING,THEN HAD A COUPLE HUNDRED POUND OVER PULL COMING OUT OF POSITION.VERY SLOWLY GAINED 100 PSI ON THE TUBING AFTER THIS SHOT. 2:40 PM OOH WITH ELINE AND SWAP OVER TO SL AND RIH WITH BRUSH AND DRIFT 4:00 PM RIG UP ELINE,RIH WITH 15'1 11/16"0 DEG PHASE STRIP GUN 5:10 PM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 540 PM PULL INTO POSITION AND PERFORATE 12,758'-12,773'WITH 15 1 11116"0 DEG PHASE STRIP GUN. 645 PM OOH WITH ELINE AND SWAP OVER TO SL AND RIH WITH BRUSH AND DRIFT 7:00 PM RIG DOWN ELINE AND SL TURN WELL OVER TO OPERATIONS TO BOL, WELL SHUT.IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL 912 PREVIOUS TOTAL COST (HRS) 9/21/15 WELL TEST) DEFERRED PRODUCTION (BBLS) DAILY TOTAL 162 DAILY COST 24 182 CUM TOTAL 1,074 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA. LAST SPILL 500 97 DEGF 600 N/A N/A 922/1S OPERATORS Day DSM DANIEL CLARK Office (907)6531236 Cell (907)978,1132 email clan/el.Elark(cpsavantalask,o:oo Night DSM DANIEL CLARK Office Cell email • • Savant Alaska,LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 9/27/16 LEASEANU,r_.i u„ BER OL RUNG .. Badami-B1-11A 115006 DA.S 9 NUMBER 6 N..ND 13,225' NDNBER 1 NSB 9resenIOveraI:on NON PRODUCTIVE TIME CONTRACTOR ANDRIO NO B1-11A PERFORATIONSIy 0.0 CumulaRve 0.0 POLLARD SL UNIT HSE I I Accidents I I Incidents I I ,Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS,HEATER AND TRIPLEX(ULSO) 1210 53.78 6467.38 POLLARD-ELINE SERVICES 640,476.78 (SERVICE CHARGE,PRESS CONTROL TOOLS,3 21'GUNS) 6000 POLLARD-SL SERVICES 12 $270 f5,240.00 50.00 50.00 soon 60.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 1 13,119'-13,140' 21' A5 111116"SPIRAL STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS 2 13,099-13,119' 21' A5 111)16"10.5'SPIRAL a 1025 SNAKE STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS 3 13,O7T-13,099' 21' AS 1 11/18.10.5.SPIRAL 410.6 SNAKE STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS TIME LOG TIME DESCRIPTION 545 AM DAILY OPS MEETING AND MORNING TOOLBOX 6.15 AM RIG UP ELINE 7:45 AM PT LUBRICATOR TO 4000 PSI 9:00 AM RIH WITH 21'1 11/16"SPIRAL STRIP GUN 515 AM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 9:45 AM PULL INTO POSITION AND PERFORATE 13,119'-13,140'WITH 21'1 11/16"SPIRAL STRIP GUN.NO PRESSURE CHANGE.POOH 1045 AM OOH WITH ELINE AND SWAP OVER TO SLAND RIH WITH BRUSH AND DRIFT 1200 PM RU ELINE 1230 PM RIH 10TH 10.5 1 11/16"SPIRAL STRIP GUN AND 10.5 1 11/16"SNAKE STRIP GUN 1:20 PM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 150 PM PULL INTO POSITION AND PERFORATE 13,098'-13,119'WITH 10.5'1 11/18"SPIRAL STRIP GUN AND 10.5'1 11/18"SNAKE STRIP GUN.NO PRESSURE CHANGE.POOH 2:45 PM OOH WITH ELINE AND SWAP OVER TO SLAND RIH WITH BRUSH AND DRIFT 000 PM RIG UP ELINE,RIH WITH 10.5'1 11/16"SPIRAL STRIP GUN AND 13.5'1 11/16"SNAKE STRIP GUN 650 PM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 520 PM PULL INTO POSITION AND PERFORATE 13,077'-13,098'WITH 10.5'1 11/16"SPIRAL STRIP GUN AND 10.5'1 11418"SNAKE STRIP GUN.NO PRESSURE CHANGE.POOH 6:00 PM OOH WITH ELINE AND SWAP OVER TO SLAND RIH WITH BRUSH AND DRIFT 730 PM RIG UP ELINE,RIH WITH 15'1 11/16"SPIRAL STRIP GUN e,35 PM CANNOT MAKE IT INTO THE BOTTOM POGLM;WORK TOOLS FOR 30 MINUTES BEFORE POOH.AFTER INSPECTING TOOLS AT SURFACE IT APPEARS THAT THE BOTTOM 10'OF GUN WAS MAKING IT THROUGH THE POGLM BUT THE UPPER 10'GUN WAS NOT. 1000 PM 006 WITH ELINE.RIG UP SL FOR BRUSH AND DRIFT RUN 1130 PM OOH WITH SLAND RIG DOWN 11.45 PM FINISH LOADING GUN FOR FIRST RUN TOMORROW. WELL SHUT4N TIME DAILY PRODUCTION1115WELL FROM PREVIOUS LAL 750 PREVIOUS TOTAL COST (HRS) 921/15 WELL TEST) DEFERRED PRODUCTION DAILY TOTAL 162 (RBCS) DAILY COST 24 162 CUM TOTAL 912 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 600 97 DEG# 600 N/A N/A 9/22)15 OP ER DayM DANIEL CLARK Office (0071659-1236 Cell (9C7)978-44132 email daniel.clark@asavantalaska llirli Night DSM DANIEL CLARK Office Cell email o • Savant Alaska,LLC SAT DAILY DRILLING(WORKOVER REPORT ALASKA DATE 9/26/16 LEASE AND WELL No Badami-B1-11A AFEN115006 DAYS 8 NUMBER OF RUNS MaTMD 13225 NUMBER FWARMS 6 0 5reS0Tt Operation NOD PRODUCTIVE RA 7 CONTRACTOR AND G NO B1-11A PERFORATIONS Dailyy 0.0Comulanve 0.0 POLLARD SL UNIT HSE I I Accidents I I Incidents I Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS NOSI IFR HOLR (IN CONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNRS,HEATER AND TRIPLEX(ULSO) _37L 33.78 3W5.86 POLLARD•ELINE SERVICES 321 1442 65 (SERVICE CHARGE,PRESS CONTROL TOOLS,110 GUNS) 10.00 POLLARD-SL SERVICES n 41/c 3152000 $0.00 30.00 30.00 WOO PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 1 13,166'-13,176' 10' A5 111116"SNAKE STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS 2 13,156'-13,166' 10' A5 111/16"SPIRAL STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS 3 13,14T-13,156' 9' A5 111/16"SPIRAL STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS TIME LOG TIME DESCRIPTION 545 AM DAILY OPS MEETING AND MORNING TOOLBOX 6:15 AM ELINE PERFORMING TOOL MAINTENANCE.REREADING AND LOADING GUNS. 9:15 AM RU ELINE 9.45 AM PT LUBRICATOR TO 4000 PSI 1000 AM RIH WITH 10'1 11/16"SNAKE STRIP GUN 11100 AM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 1200 PM PULL INTO POSITION AND PERFORATE 13,166'-13,176'WITH 10'111/16"SNAKE STRIP GUN.NO PRESSURE CHANGE.POOH 1:00 PM OOH WITH ELINE AND SWAP OVER TO SL AND RIH WITH BRUSH AND DRIFT 2:15 PM RU ELINE 2:30 PM RIH WITH 10'1 11/16"SPIRAL STRIP GUN 3:20 PM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 3:55 PM PULL INTO POSITION AND PERFORATE 13,156'-13,166'WITH 10'1 11/16"SPIRAL STRIP GUN.NO PRESSURE CHANGE.POOH 445 PM OOH WITH ELINE AND SWAP OVER TO SL AND RIH WITH BRUSH AND DRIFT 545 PM RU ELINE 6:00 PM RIH WITH 10'1 11/16"SPIRAL STRIP GUN 7:00 PM LOG CORRELATION PASS AND SEND IT TO TOWN FOR APPROVAL 7:30 PM PULL INTO POSITION AND PERFORATE 13,147'-13,156'WITH 10'1 11/16"SPIRAL STRIP GUN.NO PRESSURE CHANGE.POOH 630 PM OOH WITH ELINE.RIG UP SL FOR BRUSH AND DRIFT RUN 9:30 PM OOH WITH SL AND RIG DOWN 9:45 PM FINISH LOADING GUN FOR FIRST RUN TOMORROW. WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL 168 PREVIOUS TOTAL COST (HRA) 9121/15 WELL TEST) DEFERRED PRODUCTION DAILY TOTAL 162 (RBCS) DAILY COST 24 162 CUM TOTAL 750 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 625 97 DEGF 625 N/A WA 9/22/15 OPERATORS Day DAM DANIEL CLARK Office (907)6531236 Cell (907)978-4132 email daniel.clark@saoantalaska.com Night USM DANIEL CLARK Office Cell email • • Savant Alaska,LLC SA ANT ALASKA DAILY DRILLING I WORKOVER REPORT DATE 9/25/16 LEASE AND VVELLNo. Badami-61-11A 115006 cps 7 NUMBER Of RUNS M ..MD 13,225' NUMBER FMIaRUNS Present Operation NONPB E 'CONTRACTOR AND RSD NO B1-11A PERFORATIONS Daily 0.0T Cumulative 0.0 CNIR POLLARD SL UNIT HSE I I Accidents I I Incidents I I $pills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Dairy Costs DESCRIPTION HOUR.. ccs PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS HEATER ANOTRIPLEX(ULSD) 2480 83 78 {93].44 POLLARD-ELINE SERVICER 514,9]1.61 (SERVICE CHARGE.PRESS CONTROL,TOOLS,210'GUNS) 30.93 30.00 30.00 WOO 30.00 WOO PERFORATION DETAILS RUN U PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 1 13,186'-13,196' 10' _ AS 111/16"SNAKE STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS 2 13,178'-13,166' 10' A5 111/16"SNAKE STRIP GUN SLIGHT OVERPULL COMING BACK THROUGH RESTICTIONS TIME LOG TIME DESCRIPTION 545 AM DAILY OPS MEETING AND MORNING TOOLBOX 8:15 AM RIG UP SL ON 81-11A 725 AM RIH WITH 1.75"LIB TO GETA PICTURE OF WHAT WE ARE RUNNING INTO DOWN IN THE POGLM AND REDUCING NIPPLE. 7:40 AM DUE TO THE FLAT SHOULDER ON THE LIB IT TOOK A MINUTE TO JUMP INTO THE TOP POGLM.RIH AND TAG OBSTRUCTION IN BOTTOM POGLM.POOH 8:20 AM OOH WITH LIB;LOOKS LIKE GUN DEBRIS 8:45 AM RIH WITH 1.75"BAILER AND BREAK THROUGH THE OBSTUCTIONS IN THE POGLM AND REDUCING NIPPLE.NO DEBRIS CAME BACK,BUT WE DID GET SOME SCALE. 955 AM POOH WITH BAILER 1020 AM RIH WITH BLB AND 5'OF1.75"WEIGHT BAR AND BRUSH THE RESTRICTIONS ABOUT 6 TIMES. 11:20 AM POOH WITH BLB 12.00 PM RIG DOWN SL AND RIG UP ELINE 12:30 PM PT ELINE LUBRICATOR TO 4000 PSI 12:45 PM RIH WITH 20'OF SNAKE GUNS AND NO SWEDGE ON THE BOTTOM 1:30 PM SET DOWN ON THE REDUCING NIPPLE AND COULD NOT GET DOWN. 155 PM POOH WITH THE 20'GUN. 245 PM OOH WITH THE 20'GUNS AND LAY LUBRICATOR DOWN TO DISCUSS THE OPTIONS MOVING FORWARD. 430 PM RIG ELINE BACK UP AND LOAD 10'GUN 5.30 PM LOG CORRELATION PASS AND SEND TO TOWN 6.30 PM SHOOT 13,186'-13,198'WITH 1 11/16"SNAKE STYLE STRIP GUNS. 7:30 PM OOH WITH 10'GUN.LAY DOWN ELINE AND PICK UP SL 7:45 PM RIH WITH SL TO PERFORM CLEANOUT HAD TO BEAT THROUGH THE DEBRIS AT THE REDUCING NIPPLE. 845 PM OOH WITH SL,PICKUP ELINE LUBRICATOR AND RIH WITH 10'GUN 10:10 PM LOG CORRELATION PASS AND SEND TO TOWN. 1035 PM SHOOT 13,178'-13,186'WITH 111/16"SNAKE STYLE STRIP GUNS.POOH 11:50 PM OOH WITH ELINE.RIG DOWN ELINE AND RIG UP SL FOR CLEANOUT 1215 AM RIH WITH SL AND BLB TO CLEAN THE DEBRIS FROM THE TUBING. 1:00 AM 00H WITH SL,RIG DOWN AND MOVE OVER TO B1-IBA,B1-36 AND B1-38 FOR CLEANOUTS 500 AM CLEANOUTS COMPLETE. WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL 426 PREVIOUS TOTAL COST (HRS) 9/21115 WELL TEST) DEFERRED PRODUCTION DAILY TOTAL 162 (BBLS) DAILY COST 24 162 CUM TOTAL 588 _CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 615 97 DEGF 615 N/A WA 8/22/15 OPERATORS Day DSM DANIEL CLARK Office 0071659-1236 CeII (0071078-4132 email daniel.clark@savantalaska.com Night DSM DANIEL CLARK Office Cell email • S SAANT Savant Alaska,LLC ---- ------- -- DAILY DRILLING!WORKOVER REPORT AL_ASKA 8373 9/24/16 LEASE AND WELL ND. Badami-B1-1171 „, 115006 DAYS 6 NUMBER OF RUNE May MD 10,155' NJMeEP2a8.s51583 Present Operation XON RRDD TIME ME CONTRACTore AND RIG NO B1-11A PERFORATIONS Dailyy .mutative 0.0 POLLARD SL UNIT HSE I I Accidents I I Incidents I I SPllls I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costa DESCRIPTION HOURS COST PER HOUR GALLONS COs PER GALLON TOTAL DIRRTY DIESEL PUMPED DOWN DLE _0160 5201 64,052.14 DIESEL FOR POLLARD UNITS HEATER AND TRIPLEX(ULSD) _7110 5318 Won PoLLARD•ELINE SERVICES (SERVICE CHARGE,PRESS CONTROL,TOOLS) 30 W 60.00 60.00 30.W 60.00 PERFORATION DETAILS RUNS PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 5:45 AR DAILY OPS MEETING AND MORNING TOOLBOX 615 AM RIG UP ELINE ON B1-11A 8:15 AM HOT CHECK TOOLSTRING AND BEGIN ARMING GUNS 8:40 AM STAB ON AND PRESSURE TEST LUBRICATOR TO 4000 PSL FIND A LEAKING ORING AT CROSSOVER;REPLACE AND FINISH PT. 835 AM RIH WITH 20'OF 1 11116"SPIRAL PERF GUN WITH 1.70'SWEDGE ON THE BOTTOM.DID NOT SEE AS MUCH ASA BOBBLE GOING THROUGH THE TOP POGLM BUT UNABLE TO PASS THROUGH BOTTOM POGLM.PULL UP TO TOP POGLMN AND FIND THAT TOOLS COME BACK THROUGH POGLM AND FALL FREELY THROUGH THE POGLM. 12:30 AM OOH WITH GUNS;DISARM GUNS AND LOAD NEW SNAKE STYLE GUNS. 240 AM RIH WITH 20'OF 1 11/16"SNKAE STYLE GUNS WITH SWEDGE ON THE BOTTOM. 345 PM SET DOWN ON BOTTOM POGLM AND CANNOT PASS.LIGHTLY WORK TOOLS. 410 PM RIG UP SHOT AND BEGIN PUMPING DIESEL.PUMP A TOTAL OF 48 BBLS OF DIRTY DIESEL TO CLEAR OUT THE POGLM.WORK TOOLS TO TRY AND PASS THROUGH POGLM.COULD NOT GET THROUGH 5:40 PM POOH WITH GUNS. 6.48 PM OOH WITH THE GUNS.DISARM GUNS AND CHANGE OUT TOOLSTRING. 7:30 PM RIH WITH DRIFT ON ELINE.RUN THE SAME TOOLSTRING AS THE GUN RUNS EXCEPET WE CHANGED THE GUNS OUT FOR 1.75"SPANDS AND 10'OF WEIGHT BAR WITH THE 1.70"SWEDGE. 8:35 PM SET DOWN ON BOTTOM POGLM AND CANNOT PASS THROUGH.WORK TOOLS LIGHTLY AND POOH. 930 PM OOH WITH ELINE;RIG DOWN. 10:00 PM RIG DOWN COMPLETE 6:00 PM SIMULTANEOUS OPERATIONS WITH SL-CLEANOUTS ON B1-36,B1-38 AND B1-18A UTILIZING SAVANT GROVE CRANE 1.00 AM WELLS WERE IN ROUGH SHAPE;COMPLETE CLEANOUTS,RIG DOWN AND STAGE UNIT WELL IHRSI TIME DAILY PRODUCTION WELL TEST) FROM PREVIOUS TOTAL 264 PREVIOUS TOTAL COST (HRS) 9121/15 WELLTEST) DEFERRED PRODUCTION DAILY TOTAL 162 ' (RBCS) DAILY COST 2a 162 CUM TOTAL 426 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL N/A 97 DEGF N/A N/A N/A 9/22/15 OPERATORS Day DSM DANIEL CLARK Office (907)6551236 Cell (907)978,132 email daniel.clark@SaAantalaska.cTl n1 Night DSM DANIEL CLARK Office Cell email • S SA ANT Savant Alaska,LLC --— -- DAILY DRILLING I WORKOVER REPORT ALASKADATE 9/23/16 LEASE AND WELL NO Badami-61-11A A 115006 DAYS 5 NUMSER�3NS Max MD 13,206' NUMBER OF MISRNNS Present Operation NON moo TIM wmic CACTOR AND RNO B1-11A PERFORATIONS Daily u 0.0 Cumulative 0.0 POLLARD SL UNIT HSE I I Accidents I 1 Incidents I I Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COs•PER GAL LTOTAL • POLLARD-SL CLEANOUT AND FUT.(12 HR MINIMUM) 12 4250 64,210.03 DIESEL FOR POLLARD UNITS(ULSD) _'0 5378 $1o2oe POLLARD-ELINE SERVICES $11,064.32 (SERVICE CHARGE,PRESS CONTROL GUNS TOOLS) Woo WOO 64.00 WOO 64.00 64.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 1 13,106'-13,206' 10' AS 111116"SPIRAL STRIP GUN GD NOT ENCOUTER ANY ISSUES TINE LOG TIME DESCRIPTION 5:45 AM DAILY OPS MEETING AND MORNING TOOLBOX 6.15 AM RIG UP SL ON B1-11A 6:45 AM RIH WITH SL DUMMY GUN DRIFT;ENCOUTNERED NO ISSUES WITH THE POGLMS,REDUCING NIPPLE OR LINER TOP 745 AM OOH WITH SL;RIG DOWN SL UNIT AND RIG UP ELINE 10:30 AM ELINE RIGGED UP;OP CHECK TOOLS AND ARM 10'1 11/16"SPIRAL GUN. 11:15 AM STAB ON AND PRESSURE TEST LUBRICATOR TO 4000 PSI.FIND A LEAKING NEEDLE VALVE;REPLACE IT AND RETEST. 1145 AM RIH WITH 10'111/16"SPIRAL PERF GUN.RIH SLOWLY AND EXTREMELY SLOWAROUND THE POGLMS,REDUCING NIPPLE AND LINER TOP 2:15 PM SEND TIE-IN LOG TO TOWN FOR APPROVAL 315 PM PERFORATE 13,198'-13,206':CCL STOP DEPTH AT 13,189',CCL TO TOP SHOT=7'.POOH.THERE WAS NO CHANGE IN TUBING PRESSURE AFTER SHOT 780 PSI BEFORE AND AFTER SHOT. 442 PM OOH WITH GUN;CONFIRM GOOD FIRE.RIG DOWN SPENT FUN AND PREPARE 2ND GUN AND TOOLSTRING FOR RUN#2. 550 PM RIH WITH 20'OF 1 11/16"SPIRAL PERF GUN.ENCOUNTER A LITTLE TROUBLE GETTING IN BOTH THE POGLMS AND UNABLE TO GET THROUGH THE REDUCING NIPPLE. 7:40 PM AFTER WORKING TOOLS AND TRYING TO GET PAST THE REDUCING NIPPLE;POOH. 8:51 PM OOH WITH GUN.THE TOOLS CONFIRMS THE SUSPICIONS THAT THE BOTTOM OF THE GUN CAUGHT THE REDUCING NIPPLE IN TURN BUCKLING THE SPIRAL GUNS. 9:15 PM RIG DOWN ELINE AND MAKE A PLAN FOR THE MORNINGS RUNS 1000 PM RIG DOWN COMPLETE WELL SHUT-IN TIME GAILY PRODUCTION FROM PREVIOUS TOTAL 102 PREVIOUS TOTAL COST TENTI (HRS) 9I21I15 WELL TEST) DEFERRED PRODUCTION DAILY TOTAL 162 (RBCS) DAILY COST 24 162 CUM TOTAL 264 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 780 PSI 97 DEGF 780 PSI N/A N/A 9/22/15 • OPERATORS Day DSM DANIEL CLARK Office (907)631236 Cell (907)9784132 email danlclilalk@savanialaska.cotn • Night DSM DANIEL CLARK Office Cell email • • • Savant Alaska,LLC SA ANT ----- -----------------— DAILY DRILLING/WORKOVER REPORT ALASKA DATE 9/22/16 LEASE AND.wELLRO DAYS 4 • NUMBER OE610, 316'Ra M.MD NUMBEROF Badami-B1-11A 115006 Present OPe,ahon, NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-11A PERFORATIONS y 0.0 Cumulative 0.0 POLLARD SL UNIT HSE I I Accidents I I Incidents I I Spills I COMMENTS SHOT SPRUNG A LEAK AND WAS SHUT DOWN.SAVANT HSE COMPLIANCE OFFICER RECORDED THE SPILL AS 3/4 GALLON OF DIRTY DESIEL.TWO BAGS OF SNOW AND GRAVEL MIX WAS RECOVERED AND PUT INTO SPILL HOPPER 113. Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLC.N TOTAL POLLARD-SL CLEANOUT AND FILL TAG a 3270 32140 DIESEL FOR POLLARD SL UNIT(ULM) 18T 3379 Sea DIRTY DIESEL PUMPED DOWNHOLE WITH HOT°AFRO°,(73 BDLS) SOCA 3201 SAM f0 30 Sa PERFORATION DETAILS RUN. PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 11:00 AM START RIG UPON B1-11A,FILL SHOT(SAVANT HOT OIL TRUCK).MEETING WITH BOTH ELINE AND SLICKLINE CREWS. 100 PM RIH WITH 3.8"HELICAL PARAFFIN CUTTER WHILE PUMPING 180 DEF DIESEL;CUT HEAVY PARAFFIN FROM 2632'-3372'AND COULD NOT MAKE A HOLE.PUMPED A TOTAL OF 63 BBLS OF DIESEL. 300 PM RELOAD SHOT WITH 64 BBLS DIRTY DIESEL AND SPOT NEXT TO SL UNIT. 3:20 PM RIH WITH 2.8"HELICAL PARAFFIN CUTTER WITHOUT PUMPING(WELL IS FLUID PACKED)AND CUT HEAVY PARAFFIN FROM 3328'-3372';TOOLS FELL FREE AND DRIFT TO POGLM. 3.50 PM RIH WITH 3.5"SCRATCHER WITHOUT PUMPING;CUT MEDIUM PARAFFIN FROM 3360'-3390'.TOOLS FALL FREE TO PAOGLM. 4:45 PM RIH WITH 3.8"HELICAL PARAFFIN CUTTER WITHOUT PUMPING;CUT HEAVY PARAFFIN FROM 3356'-3548'AND TOOLS FALL FREE TO POGLM AT 3972'. 530 PM RIH WITH 2.125"BLB.BEAT BRUSH THROUGH POGLM AND DRIFT TO 6000'WITH NO ISSUES.MAKE SEVERAL PASSES THROUGH THIS INTERVAL WITH THE BLB. RIH WITH 1.8"GR WHILE PUMPING HOT DIESEL.DRIFT TO THE NIPPLE REDUCER.DID NOT ENCOUNTER ANY ISSUES ENTERING EITHER POGLM BUT WITH THE SHOULDER ON THE GR WE COULD NOT GET PAST THE 615 PM NIPPLE REDUCER.WE HAVE NEVER HAD THIS ISSUE BEFORE;BUT THIS IS THE MOST BLUNT TOOL WE HAVE RUN;IT IS NOT REPRESENTATIVE OF THE STRIP GUNS.PUMP A TOTAL OF 10 BBLS OF DIRTY DIESEL BEFORE THE SHOT SPRUNG A LEAK AND WAS SHUT DOWN. 7:00 PM RIG DOWN SL AND SHOT. 930 PM CREW FINISHED INSTALLING THE NEW STARTER ON THE ELINE UNIT.OP CHECK ELINE UNIT,UNIT SEEMS TO BE FULLY OPERATIONAL. WELL IRRSIN TIME DAILY PRODUCTION TEST)FROM PREVIOUS TOTAL 14 PREVIOUS TOTAL COST (HRS) 9nin5 WELL TEST) DEFERRED PRODUCTION DAILY TOTAL 88 (BRCS) DAILY COST 13 162 CUM TOTAL 102 CUM TOTAL COST-ESTIMATED PRE-PERF WELLHEAD PSI PRE-PERF WELLHEAD TEMP POST-PERF PSI DAYS SINCE LAST LTA'. LAST SPILL POST-PER TEMP 181 PSI NIA 9122115 97 DEGF OPERATORS DSM'. DANIEL CLARK Office 0071 6541236 Cell (907)978,132 email daniel.clark@savantalaska.com Night DSM DANIEL CLARK Office Cell email • Savant Alaska,LLC SA ANT ---- ----- DAILY DRILLING I WORKOVER REPORT ALASKA DATE 9/21/16 LEASE,.WELL NC DPYS NUMBER OF RUNS Max MD NUMBER OF M1$RVNS Badami-Bt-1IA 115006 30 N/A ATecem Operator' NON PRODUCTIVE TIME CONTRACTOR AND RIC NO a STANDBY 'Iy 0.0 Cumulative 0.0 N/A I I Accidents I I Incidents I I Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costa DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL fA f0 W SO SO PERFORATION DETAILS RUN PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION IHL LI I IAAc-PERT.: WELL SHDT4N TIME DAILY PRODUCTION(BOPD FROM PREVIOUST14 PREVIOUS TOTAL COST (HRS) 9/21/15 WELL TEST) DEFERRED PRODUCTION DAILYLYTOTAL O (RBCS) DAILY COST 0 tea CUM TOTAL 14 CUM TOTAL COST-ESTIMATED DAYS SINCE LAST LTA: PERSONNEL: LAST SPILL'. NSA • On Location N/A OPERATORS REP. Day DSM DANIEL CLARK Office (90])69-1235 Celt (90719704132 email daniel.Clarkesavantalaska.com Night DSM DANIEL CLARK Office Cell email II) S SA ANT Savant Alaska,LLC ALASKA DAILY DRILLING I WORKOVER REPORT aATF 9/20116 LEASE AND aELLNO acE NO Badami-B1-114 115006 DA., NUMBER NUMBER OF RUNS M,.MD NIA NUMBER OF MISRUNS 0 Present OPerzeon NON PRO...TIME CONTRACTOR AND Ric NO STANDBY ,Lill. y 0.0 Curnulative 0.0 N/A I I Accidents I I Incidents I I I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS. Safety Walk Around Day Safety Walk Around Night Daily Cos. DESCRIPTION HOURS COST PER HOUR GALLO5 COST PER GALLON TOTAL SO SO SO SO SO So SO SO SO PERFORATION DETAILS R.,..n PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATKNN ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUSTOTAL 14 PREVIOUS TOTAL COST (HRS) 9/21/15 WELL TEST) DEFERRED PRODUCTION DAILYLYTOTAL 0 + (RBCS( DAILY COST 0 162 CUM TOTAL 14 CUM TOTAL COST-ESTIMATED DAYS SINCE LAST LTA: PERSONNEL: LAST SPILL: NAA On LOCaIIOn N/A BROW-ORS Day0934 DANIEL CLARK Office (907)659-1236 Cell (907)9284132 email danlel.clarklasavantalaska.com Night DSM DANIEL CLARK Office Cell email w s Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 9/19/16 LEASE AND WELL Na DAYS NUMPER Max - - r MD NUMBER DAF Mi5RUN5 Badami-B1-11A 115006 1 1 13,232' 0' PresentOPeraton NON PRODUCTIVE TIME CONTRACTOR AND RIG No 81-11A PERFORATION PREP WORK Uaily 0.0 Cumulative 0.0 Pollard SL Unit HSE I ( Accidents I I Incidents I I Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS. Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL POLLARD-SL CLEANOUT AND FILL TAG 3 $270 $610 DIESEL FOR POLLARD SL UNIT(ULSD) 32 $379 $12 SO SO $0 SO $O $0 $0 PERFORATION DETAILS RUN M PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 10:00 AM SAFETY MEETING 10:45 AM RIG UP POLLARD SL 11:05 AM RIH WITH 1.9"SCRATCHER AND TTL 11:45 AM TAG FILL AT 13,198'SLM(13,232'MD FROM BELOW CORRECTION) 12:00 PM TAG TT AT 10,290'SLM AND CALCULATE CORRECTION AS 34'. POOH 12:30 PM OOH RIG DOWN POLLARD SL 1.00 PM RIG DOWN COMPLETE "'NOTE:BOBBLED THROUGH TOP POGLM BUT DID NOT SEE ANY BOBBLES FOR THE BOTTOM POGLM,NIPPLE REDUCER OR THE LINER TOP. WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL D PREVIOUS TOTAL COST (HRS) 9121/15 WELL TEST) DEFERRED PRODUCTION DAILY TOTAL 14 (RBCS) DAILY COST 1 162 • CUM TOTAL 14 CUM TOTAL COST-ESTIMATED DAYS SINCE LAST LTA: PERSONNEL: LAST SPILL: N/A On Location N/A OPERATORSDay DSM DANIEL CLARK Office (907)659-1236 Cell (907)978-4132 email daniel.clark@savantalaska.com Night DSM DANIEL CLARK Office Cell elnall SOF T� �w\�����j,tv THE STATE Alaska Oil and Gas ��r�,;, �, of AL ASK A Conservation Commission 4f ��-ih__== 333 West Seventh Avenue k z- 7.-111.:_-1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 * Main: 907.279.1433 OF ALAS�P Fax• 907.276 7542 www.aogcc.alaska gov Conrad Perry N�f�� - Drilling Manager SO' Savant Alaska, LLC 601 W. 5th Ave., Ste. 310Q3 Anchorage,AK 99501 Li Re: Badami Field, Badami Oil Pool, B1-11A Sundry Number: 315-511 Dear Mr. Perry: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a1/ Cathy . Foerster Chair DATED this 283 day of August, 2015 Encl. RBDMS SPP 0 4 2015 RECEIVED STATE OF ALASKA AUG 2 �12015/ ALASKA OIL AND GAS CONSERVATION COMMISSION CU-S Q> z' l� ✓S APPLICATION FOR SUNDRY APPROVALS AnGou 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑✓ ` Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Savant Alaska LLC Exploratory ❑ Development Q - 198-034 ✓ 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 50-029-22829-01 , 7. If perforating: Lo, c%� 8.Well Name and Number: 7 t ,c What Regulation or Conservation Order governs well spacing in this pool? 20 mc.-�:of , a t B1-11A - Will planned perforations require a spacing exception? Yes ❑ No ID 9.Property Designation(Lease Number): 10.Field/Pool(s): ,417L- 367011 Badami Field, Badami Oil Pool 11. i 4,17g,Z1,/fPRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,375' ^ 10,475' ' 13,149' 10,307' Fish(a113 2' Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 110' 110' Surface 5,025' 9 5/8" 5,059' 4,534' 5750 3090 Intermediate 10573 7" 10,606' 8,434' 11220 8510 Production Liner 2,944' 4 1/2" 13,375' 10,475' 7780 6350 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12606-13246 9925-10379 4.5" L80 10,324' Packers and SSSV Type: 7"x 4 1/2"HES TNT Pkr/no SSSV Packers and SSSV MD(ft)and TVD(ft): Pkr @ 10274/8152 TVD 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date for 21-Aug-15 15.Well Status after proposed work: Commencing Operations: OIL 2- WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stephen Ratcliff Email stephen.ratcliff( cookinlet.net Printed Name conrad perry Title Drilling Manager Signature (. / Phone 07-727-7404 Date July 30th,2015 COMMISSION USE ONLY Conditions of approval: Notify Cors on so that re resentative may witness Sundry Number - `` 315 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No RI Subsequent Form Required: /6. yQy APPROVED BY � Approved by: i)4e.....g,j4"...._ aief7 COMMISSIONER THE COMMISSION Date:U'1� 1 S )�' �`t' Y Submit Form and midi10� ase r k oppRidOttlAtfor 12 mghths from the date of approval. Attachments inpuplicate m �/ , 2///,j 8.2/-/S— 1. WELL NAME - Badami B1-11A Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing. Current Perforations MD TVD 13,206' - 13,246' 10,295' - 10,323' 12,676' - 12746' 9,917' - 9,969' 12,606' - 12,666' 9,870' - 9,917' Scope of Work: • Rig up eLine. Test Lubricator to 3000psi • Perforate selected zones sequentially. o If 1 11/16"guns are ineffective or won't go down, pull POGLM sleeves • Re-Run POGLM Sleeves if pulled. • Rig down. Flow well General Well Information: Reservoir Pressure /TVD: 7225 psi @ 10,340" TVD (.70 psi/ft) MASP: 4846 psi (Half oil/Half gas) 7225 psi - (5170'well with .35 psi/ft oil) -( 5170'with .1 psi/ft gas gradient) 4846 psi = 7225psi - 1809psi -570psi Wellhead Type/Pressure Rating: 11" Multibowl 5K Wellhead Well Type: Oil Well Estimated Start Date: September 15th, 2015 CIE Drilling Manager: CIE Sr. Drilling Engineer: CIE Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-9738 (907) 433-3822 conrad.perry@CookInlet.net Stephen.Ratcliff@CookInlet.net David.Kumar@CookInlet.net 3 Program 1. Clean up well bore with slick line/diesel washes. 2. Shut well in. 3. Rig up eLine. Test lubricator to 5000 psi. 4. Make dummy run with 1 11/16" sinker bar. Note max angle through perfs is 48 degrees 5. Perforate with 1 11/16" strip guns from 13,147' to 13,206'. Approximate.25" entry hole and 19" of API penetration. 6. Rig down eLine and put well to production to determine small gun effectiveness*. 7. If production increase is seen, continue perforating entire program a. 13,147' - 13,206' 59' A5 b. 13,062' - 13,140' 78' A5 c. 12,758' - 12,793' 35' F5 8. If no production increase, rig up Slick line and test lubricator to 5000 psi 9. Recover POGLM from 4000' and from 10,155'. 10. Make dummy run with 3 1/8" drift. Note max angle through perfs is 48 degrees 11. Rig down slick line. Rig up eLine and Test Lubricator to 5000 psi. 12. Re-perforate with 3 1/8" casing guns from 13,147' to 13,206'. 13. If pressure increase is seen, continue perforating entire program a. 13,062' - 13,140' 78' A5 b. 12,758' - 12,793' 35' F5 14. Re-install GOGLMs at 10,155' and 4,000'. Perform FIT on annulus. 15. Perform no flow test or install K SSSV. *The above stepped program is designed to minimize risk and production shut-in. The POGLMs do not have to be touched if the 1 11/16"guns are effective. Their effectiveness is tested over the best 60'interval in the proposed perf adds. There are three possible outcomes with the small guns. One is success, two insufficient penetration, and three sufficient penetration, but no reservoir. 4 Current Badami B1-11A Schematic Drs Floor to(romd Level 53.9 Tree 4 1/16"5000 PSI CIW OD ID Weight Length MD ND Growl Level to Sea Level 18.6' Wellhead 13 5/8710000 psi'FMC itch inch Lbs ft fl DF SS Note:BPV removed 322/10 < 4-1/2"12.6#L-80 NSCT MOD.0152 bpf 4.500 3.958 10324 10324 8221 2° I I< 4-1/2"HES X NIP,ID(SSsv Pem®antty tt mvd Sept.m 4.500 3.813 2207 2142 4-1/2"HESDWP 4.500 1.910" 3990 3738 43° �, Holes in Tubing for Gas Lift 4000 3747 g #2 CI 14(IUCIMS)1)o Valve,BK latch,lb 1k 4000 3747 45° A K 13-3/8"CSG,68#,L-80 BTC 13380 12.415 5059 4485 44° ;, Holes it Tubing for Gas Lill 10155 8103 EJ #1(:1M(I'X:1NWS)NO Valve,Ilk Iattt,7.0 Port 10155 8103 44° Z Z 7"X 4-1/2"HES TNT PKR 7.500 3.850 10274 8183 4-1/2"XNipple 4.500 3.813 10291 8196 p 41 4-1/2"XN Nipple 4.500 3.725 10312 8213 2-3/8"X Redncitg Nipple 2.380 1.875 10316 8215 Note:2 Mir XX Aug Removed 323/10 2.380 10316 8215 ' k ELMD TT Not Logged 4-1/2"WLEG 4.500 3.958 10324 8220 ----- 7"X4-12",LNRHGRPIM 42° • Top of 4-12"Inver 12.6#,L-80 BCT MOD.0152 bpf 4.500 3.958 10430 8376 A L.(----7"LNR 29#P110 BTC 7.000 6.184 10605 8430 49° Maxims Deval im A J$ 12251 9635 12606'-12666'MD;9870'-9917 TVDSS 10/31/98 12676'-12746'MD;9917'-9964 TVDSS 10/31/98 FRACD 13206'-13246'MD;10295'-10323'TVDSS 8/8/98 IIIIIIIIIIIIIIIII PBTD 13288 10356 No. Rev.by Comm-Ms/Date 111-11 , 1 DDW Sidetrack(B1-11A)2/9/08 Location Correction Badami Unit 2 MAS Add POGIMS 4/1/02 API No.50-029-22829-01 3 SWC Set XX Plug @ 10312 9/3/07 PlO No.198-0340 ,./7 4 R Bente Updates 9/9/12 ;BC 8,19N,R20E,1426'FNL&156'FII 5 CP 7-30-15 Removed Closed m1e on perffi Lasted Revised: duly 30,2015 SAVANT 5 ALASKA 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. /~'~ -(~/'f' File Number of Well History File PAGES TO DELETE Complete RESCAN E] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: ~,//~ / ~. / Poor Quality Original'- Pages:~ [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED Logs of vadous kinds Other COMMENTS: Scanned by: Beverly Mildred Dareth~Lowell TO RE-SCAN Notes' Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is/ • • w \� O �� �y� 9 THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 'A, Q. Anchorage, Alaska 99501 -3572 AL Main: 907.279.1433 Fax: 907.276.7542 October 5, 2012 Mr. Erik Opstad General Manager, Alaska Operations Savant Alaska, LLC P.O. Box 112212 Anchorage, AK 99511 SCANNED APR 17 2013 RE: No -Flow Verification Badami Unit B1-11A PTD 1980340 Dear Mr. Opstad: On September 4, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Badami Unit well B1 -11A located on Alaska's North Slope. The well is operated by Savant Alaska, LLC (Savant). 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 in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the well was shut in and proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10 -004 — was rigged up to Badami BI -11A. The no -flow test consisted of a series of flow and shut in periods. The maximum flow rate measured was 180 standard cubic feet per hour (SCFH) quickly falling off to 40 SCFH; the flowing pressure ranged from a maximum 1.5 psi to 0.2 psi. During the shut -in monitoring periods, the maximum measured pressure was 1.8 psi. There was no liquid production to surface during the test. The AOGCC Inspector granted Savant verbal approval to place B1-11A back on production without a subsurface safety valve based on the successful no flow test. The subsurface safety valve must be returned to service if Badami B1-1 1A 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, fr 1 17 James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission i TO: Jim Regg �qe" 1 °I '/I DATE: September 4, 2012 P. I. Supervisor ( 7 FROM: John Crisp, SUBJECT: No Flow Test Petroleum Inspector Badami Unit Well B1 -11A PTD 1980340 September 4, 2012: I traveled to Savant Alaska's Badami Unit to witness a No Flow test on well B1 -11A. When I arrived on location I witnessed Badami B1 -11A rigged up with no flow equipment as required by AOGCC Guidance Bulletin 10- 004, Appendix A. Tubing & inner annulus (IA) were rigged up with hoses & open to a bleed trailer. I requested the IA valve be shut for the no -flow test. IA & outer annulus pressure gauges were at 0 psi. Short 20 -foot hose was attached downstream from a calibrated digital test gauge & flow meter with the end placed in a 5- gallon pail of water. Tubing was opened up and slight gas flow was observed (bubbling in pail of water). No liquids were flowing from well during the no flow test. Well was observed flowing for 1 hour with 0.2 psi to 0.5 psi pressure & approximately 40 SCF per hour (SCFH) gas flow. Well was shut in for 1 hour and maximum of 1.8 - psi build up was witnessed on the calibrated test gauge. Badami B1 -11A was then opened again to the 5- gallon pail of water with initial pressure of 1.5 psi & flow rate of 180 SCFH. After 5 minutes, well flowing pressure was 1 psi with approximately 40 SCFH witnessed flowing to the 5- gallon - pail of water. After 30 minutes of flow, I observed 0.8 psi flowing well pressure and approximately 40 SCFH flowing into 5- gallon pail of water. One (1) hour into - flow test, I observed 0.6 psi flowing well pressure with approximately 40 SCHF flowing into the 5- gallon pail of water. Summary: Successful 3 hour No Flow test performed & witnessed on Badami Unit B1 -11A as per no flow test procedure & equipment arraignment [20 AAC 25.265(k); Industry Guidance Bulletin 10 -004. Travel in & out of Badami was constrained by weather, resulting in minimum amount of time available for this inspection. Attachments: none SCONE[) APR ' Non - Confidential No flow test Badami Unit B1 -11A 09 -04 -12 ALASKA •AND G STATE OF AS CONSERVATION COMMISSIO. . RE COPY REPORT OF SUNDRY WELL OPERATIONS i � . { 1. Operations Abandon U Repair Well U Plug Perforations Li Stimulate U Other U , Iristall IK ,, Performed: Alter Casing Pull Tubing ❑ ❑ Alaslaa t.ittheiei Rt�Q col lb. vvC ttt►ti: 9 ❑ 9 ❑ Perforate New Pool Waiver Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended wj orage 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Savant Alaska, LLC Development 0 Exploratory ❑ ® 198 -034 3. Address: Stratigraphic E] Service ❑ 6. API Number: P. O. Box 112212, Anchorage, Alaska 99511 -2212 - 50-029-22829-01*- 00 7. Property Designation (Lease Number): 8. Well Name and Number: MM. 0367011 Badami B1 -11A 9. Field /Pool(s): Badami Field & Badami Pool (Upper Brookian) 10. Present Well Condition Summary: Total Depth measured 13,375' feet Plugs measured None feet true vertical 10,475 feet Junk measured 13,231' feet Effective Depth measured 13,149' feet Packer measured 10,274' feet true vertical 10,307' feet true vertical 8,152' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 110' 110' 1,530 psi 520 psi Surface 5,025' 9 -5/8" 5,059' 4,534' 5,750 psi 3,090 psi Intermediate 10,573' 7' 10,606' 8,484' 11,220 psi 8,510 psi Production Liner 2,944' 4 -1/2" 10,430' - 13,375' _ 8,354' - 10,475' 7,780' psi 6,350 psi Perforation depth Measured depth 12,606- 12,666 feet 12,676- 12,746 feet 13,206- 13,246 feet Open Open Open Frac'd 08 -08 -1998 True Vertical depth 9,925 -9,966 feet 9,973- 10,021 feet 10,349 - 10,325 feet Tubing (size, grade, measured and true vertical depth) 4 12.6# L -80 10,324' MD 8,277' TVD Packers and SSSV (type, measured and true vertical depth) Halliburton SSSV K -Valve I r 2,207' MD 2,196' TVD Halliburton Packer TNT 10,274' MD 8,152' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): x� 1. f None = .r1 Treatment descriptions including volumes used and final pressure: None 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 270 536 0 1156 psi 195 psi Subsequent to operation: 214 481 0 1144 psi 359 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Flowing P/T Survey Exploratory Development 0 -. Service ❑ Stratigraphic ❑ Daily Report of Well Operations Well Service Report 15. Well Status after work: ' Oil is Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP ❑ SPLUG ❑ 16. 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: 311 -109 Contact Mary Rush or Erik Opstad (907) 868 -1258 Printed Name ri •stad f Title General Manager i iii /''_ Signature � � �liI i i Phone: (907) 244 -5210 Date: 04/11/11 kr ' Or ,,, p Y ./11•(e r . Form 10 -404 Revised 10/2010 RBDp 4 f , i' "� Submit Original Only Schlumberger Flowing Pressure Survey Well: Badami B1 -11A Date: 30- Mar -2011 160 -- - — 2000 140 – 1800 – 1600 120 - - • – 1400 Q, 100 - m – 1200 10 Min Stop 103.39 10 Min Stop a 80 5 surface @ surface 1000 m � 60 -- -- — 800 780.12 10155'MD 57.61 – 600 40 — 400 444.9 ' 20 9.0' D 36.44 400.75 — 200 t 2212'MD • 49.73 2' 5.81 0 193 0 00 ^h .00 ph 00 ,\‘'D 0 .0 0 p h 0 1 0 0 0h 0 ,� 0 r.") r.") 00 0 p h 0 tx 00 r n�O p h 00 pt) 00 h 00 1\ • •00 0 O �h . 43 0 O p,• b ? ) �' � ^N . ` L O ` L 0 . 07 O H O , \ (0 • .e )• .O b` D .hq' .(Q.17. \ pp D 4 .O H O• \ .� -i I � .O '\ � O • 1:c0. ��. � • �� �� � • �� �� • ^ •�••*�••• 4b. N0. t\ N 93. t\ 0. N c5• 1. O• Nc 0. ∎\ c •, N )., \ 0. ti O• r 0. ti O• `P . ( 0. (P . `1, >. 9'` • Time • Temp (DegF) Pressure (PSI) a'41e0-1//e, FLOWING PRESSURE/TEMPERATURE SURVEY Requested Stops: MD SS Time First 10,155' We 6 min Second 3,990' nla 5 min Third 2,212 We 10 min Well: Badami B1-11A Badami Pool PE: Erik Opstad !Zane Henning Date: 3/30/2011 Service Co. Schlumberger New Tag: None 'MD Upper , Test Date Time MD SS Gauge Temperature Gauge 30-Mar-11 17:25 Pre-Job Lubricator Pressure 193.48 49.73 200 30-Mar-11 19:41 '10,155' r &a 780.12 103.39 30-Mar r -11 20:41 3990' We 444.92 57.81 30-Mar-11 21:03 i 2212' r nia 400.75 39.54 * / 30-Mar-11 22:27 Post-Job Lubricator Pressure 205.81 36_44 200 Pressure Tool: Spartek SITP (Tubing) 220 psig SICP (9-5/8"): 100 psig Comments: Flowing pressureitemprature survey to collect data for setting K-Type SSSV dome pressure • • STIAlfEE DEF A[LASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 • PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Opstad General Manager ''�j Savant Alaska, LLC APR ` 01 v P.O. Box 112212 00 Anchorage, AK 99511 -2212 Re: Badami Field, Badami Oil Pool, B1-11A Sundry Number: 311 -109 Dear Mr. Opstad: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, tOP ff Daniel T. Seamount, Jr. Chair DATED this day of April, 2011. Encl. l „ . ,, . • 00 RECEIVED STATE OF ALASKA � / 1 .y B yi w E �., ALASKA OIL AND GAS CONSERVATION COMMISSION A. APPLICATION FOR SUNDRY APPROVALS M i9 & Gas Cow Commission 20 MC 25.280 , .. 1. Type of Request: Abandon ❑ Plug for Redd! ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Pr ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing [] Time Extension 0 Operations Shutdown 0 Re - enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install K El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. SAVANT ALASKA, LLC Development in Exploratory ❑ 198 -03+4 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O. Box 112212, Anchorage, Alaska 99511 -2212 50 -029- 22829 -01 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: N/A Spacing Exception Required? Yes ❑ No El I31-11A 9. Property Designation (Lease Number): 10. Field / Pool(s): 367011 Badami Field, Badami 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): 13,375' 10,475' 13,149' 10,307' N/A Fish @ 13,231' Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20” 110' 110' 1,530 psi 520 psi Surface 5,025' 9 -5/8" 5,059' 4,534' 5,750 psi 3,090 psi Intermediate 10,573' 7' 10,606' 8,484' 11,220 psi 8,510 psi Production Liner 2,944' 4 -1/2" 10,430' - 13,375' 8,354' - 10,475' 7,780' psi 6,350 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3- Intervals 12,606'- 13,246' 9,925' - 10,379' 4 -1/2" 12.6# L -80 10,324' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" x 4 - 1/2" HES TNT Packer , ID - 3.850" I No SSSV Installed TNT Packer @ 10,274' MD (8,152' TVD) 12. Attachments: Description Summary of Proposal IO 13. Well Class after proposed work: Detailed Operations Program IA BOP Sketch I ✓I Exploratory II Development I . ,1 Service L _I 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Thursday, March 31 , 2011 Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Erik Opstad or Mary Rush Phone 907 868 - 1258 Printed Name Erik • •st. • ,, Title: General Manager Signature 0.0- �'%/���01` Phone: 907- 244 -5210 Date: Friday, April 01, 2011 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 11-109 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: /' — 1.5 .1- .- 1' L,.), # GSS lies /V 1-ts 1. Subsequent Form Required: 0 – Ye, U 6 APPROVED BY I Approved by: / / O COMMISSIONER THE COMMISSION Date: Form 10 -403 Revise p S APR 6 0 ZOt Submit in Duplicate Q iG1NAL. , r/ 74 SI'll • • TREE = 4- 1/16" 1 5000 PSI / CM/ WELLHEAD = 13 -5/8' / 10000 PSI / FMC B 1 11 A SAFETY NOTES: WELL REQUIRES A SSSV. ACTUATOR = KB. ELEV = 53.9' BF. ELEV = 18.6' KOP = 2207' 1- 14.1/2" HES X NP, ID = 3.813" Max Angle= 49 @ 12251 Datum MD = 3990' H4 -1/2" HES DWP, ID = 1:910" I Datum TV D I 4000' 1-1 HOLES IN TBG FOR GAS LIFT I GAS LIFT MANDRELS (POGLMS) 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" H 5059' 1-4I I ED MD TVD DEV TYPE Eons PORT DATE 4000 ® 10155 8854 POGLM DOME SO 20 04/02/02 * POGLM WITH GL MANDRELS Minimum ID =1.875" @ 10316' I 10145' H4-1/2" HES DWP, D= 1.910° I 2 -3/8" X NIPPLE REDUCER - 11- I 10155' I-1 HOLES IN TBG FOR GAS 'LIFT I z I 10274' 1-17" X 4-1/2" HES TNT PKR D = 3,850" I 1 10291' I- 14 -1/2" X NIP, D= 3.813" I 11 , L 10312' 1-14-1/2' XN NIP, ID = 3.725" 1 10316' I— 4 -1/2" X 2 -3/8" NIP REDUCER D = 1.875" (03/29/10) 4 -1/2" TBG, 12.6 #, L -80 NSCT, - 10324' I .— 1 10324' 1 -14 -1/2" WLEG, = 3.958" I .0152 bpf, D = 3.958" I-J ELMD TT NOT LOGE® I . I 10430' I -17" X 4 -1/2" LNR HNGR PKR ID = 4.438" I 17" LNR 29 #. P110 BTC, ID = 6.184" H 10605' I —A I� PERFORATION SUMMARY REF LOG' SBT ON 04/05/98 ANGLE AT TOPPERF: 47 @ 12606' Note: Refer to Production DB for historical pert data SIZE SPF MERVAL (MD) Opn /Sqz DATE 12606 - 12666 0 10/31/98 12676 - 12746 0 10/31/98 13206 - 13246 FRAC'D 08/08/98 I I PBTD H 13288' 1 ♦��etr 4-1/2" LNR, 12.6 #, L -80 BTC MOD —1 13375' •■■••■••■• .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS BADAMI 7? ?? ORIGINAL COMPLETION 02/09/08 RCT /PJC SET BR/ (02 /04/08) WELL: B1 -11A 03/01/98 DDW SIDETRACK (B1 -11A) 02/09/08 PJC LOCATION CORRECTION PERMIT No: "1980340 03/30/99 JTP UPDATE INFORMATION 03/29/10 CJN/PJC PULL BR' (01/28/08 API No: 50- 029 - 22829 -01 04/01/02 MAS ADD POGLMS 03/29/10 GTW /PJC PULL XX PLUG & RESET NIP REDUCER SEC 8, T9N, R20E, 1426' FNL & 156' FEL 08/30/06 WRR/TLH FORMAT CORRECTIONS 02/21/11 MB /JMD ADDED SSSV SAFETY NOTE 09/03/07 SWC/PJC SET XX PLUG @ 10312' BP Exploration (Alaska) _h. Badami Wire line Rig-Up & Pressure Control System SOP - Wire line Setup Typical Pressure Control To Slop tank - Siggiurre nvd chain_ I Wellhouse , - - - Bl T I N Paric off (It }kir S ;0 ' 7,40 0. siiii e , 4 o ' 1,' Bleed Tank Hoses: I 1 1- Lime Wiper 1) Ir2" hose hardimed from lower BOP 0 to Tank with wbirpeheeks - . \ .2) 2' bow Molina from Purnp-In Sub .,, 7 T , i Plow 1 ,. to Task with flip:becks " i 3) Flow line . Sewn wiebein. Pink speaker t ime Tenter Lino \ Var4 valve open 1 4 IWO i 0 0 al ,i ,., ,, N , ,, ■ ,.■ , . Whale ,, . „'.... ''r,t Crane , I s .- 4U rea - • r 4. 1 ' Cilagram lb be i i ,j, • in” kart hareem:I Imo lower %,,,L. d k : updated 02-3 - ' BOP w Dieter with whipchedd, ) ( 2010 (summer i?„, ' (Checkrein no BOP) i tritern project) Note'. The ensnare teal Soso is to be moved to lreate: C'':''') 1-leadl CatoKeir TriPlex den slop tank end used as the high presort Logger bleed koe slier Fertillre testing ' 7" QTS - Usczd for ,. (iumilli.figiriplo Rana Other Notes: Grounding Straps • I) 2gtition %acmes 25' from bleed tanker meth boiler aalaillb" Pressure Hoses 2) Economiser stook be a mansions of Iff flea wellbooso r 25 Amin *Amid e 3) Pomp-in Sub sbovid be within Ivadi from the scaffolding ' ./..- - _I; — '4 ' Drip Pans 4) Drip pans shook] be placed snider be nmning toifipmeat and where iodinated above , 1 - 5) Reasonably maximize drunk between Cestolithale and Whileibrellhook 1 I 5 Other items to note • Placement of Melts Traitor, grounded to Triplex. ...„ IMO • Fall restraint systems to be utilized when climbing and descending wellhouse ladders ., lilt il - :..k7 • 112S Personnel monitors to be worn at ad times • Heater trunks' ensure these are off the ground as much as possible . ▪ Cranes outrigger pads are clear ot snow, ce, and are on a fir-n surface, Donnage {-3x surface area of the pads themselves) to be used during snowmen conditions to provide larger area for - ' 1 I 7 Line to sinp tan k stability during melting conditions , bareall no I P',......., ' • • SAYANT ALASKA Badami Well B1 -11A — Install K -Valve in X- Nipple @ 2207' MD Background Information Current Status: Well on production with POGLM lift gas assist. Production Rate: 26- March -2011: 243 BOPD, GOR 1937, °API 20.2 Maximum Inclination: 48.7 at 12,251' MD (9,688.47' TVD) Minimum ID: 1.875" thru 2 -3/8" X Nipple Reducer at 10,316' MD Last TD Tag: 13,210' MD (hard mechanical tag by CTU, 3/26/2010) Last Down -hole Ops: Boots & Coots CTU hydrate -plug wash, 03 March 2011. Last BHP & BHT: 9/04/10 — 3,928 psi @ 12,700' MD and 210 ° F Latest H No H2S measured at B1 -11A or observed at Badami generally. Tubing Fluids: Crude and Produced Gas Gas Lift Mandrels: Live Valve and 5/0 in POGLM (see Wellbore Diagram) Work Scope: Install K -Valve in HES X- Nipple at 2,207' MD. Nipple type and well geometry need to be considered when running a K- valve. This information needs to be recorded for future reference when the K -valve is pulled. Timing: This work must be complete by April 3, 2011 per AOGCC. Badami Logistics: Coordinate activities with Erik Opstad at Erik.Opstad@SavantAlaska.com, North Slope phone 448 -6010 (Anchorage 244 -5210) or Zane Henning Zane.Henning @SavantAlaska.com , NS phone 488 -6013. Date 03/28/2011 By: Erik Opstad S • Page 2 of 3 Procedure to Install K -Valve in B1 -11A 4%2" HES X- Nipple (3.813" ID) 1. Pump Paraffin Dispersant Slug Job 24 hours prior to arrival of Slickline Unit 2. Grease and service tree as necessary. 3. Hold pre -job safety meeting inclusive of the Savant Companyman, Slickline crew, and Little Red Services Hot Oil crew, BP Badami Operations Team Leader, BP Badami Operations Lead Technician, AES Lead, Control Room Representative and Badami Safety. 4. MIRU Slickline Unit. Insure proper COW barriers and signage are in place and that all personnel are compliant with PPE equipment requirements. 5. Pressure test lubricator to 3,000 psig. 6. RU SSV remote control to Slickline unit and test. 7. Using pump -in sub, RU LRS onto HES lubricator and Hot Oil Wash the 4.5" production tubing with 40- Barrels of 180 °F dirty diesel in conjunction with HES 4%2" brush to remove any paraffin buildup from surface to the 4%2" HES 3.813" ID X- Nipple at 2207' MD. 8. Commence well stack -out with lift gas as required to facilitate bring the well back on production at the conclusion of this job. Pump 2 — 3 barrel methanol spear down IA to dehydrate. Pump additional barrels down tubing during stack -out as deemed prudent to prevent the formation of hydrates. Coordinate with Badami Control Room. 9. RIH and drift tubing with 4%2" gauge ring from surface to below X- Nipple at 2207' MD to ensure that the tubing is free of paraffin buildup or other obstructions. POOH. Run a braided -line brush if necessary. 10. While drifting tubing as above: a. Confirm the K -Valve pressure setting is in accordance with specifications called out based on the open choke, flowing well pressure data (see attached chart). As such, the valve will be set to close at 400 psi and be open at flowing pressures above 400 psi, which will be created by choking back the well slightly at surface (see eFlow Report). Date 03/31/2011 By: Erik Opstad • • Page 3 of 3 b. Set up lock that fits the nipple profile and K -Valve assembly to X -Line setting tool. c. Assemble 0 -rings on EQ device and fix to X running prong. Assemble XO equalizing sub to K -valve (EQ device will be off seat). 11. RIH with X -Line running tool in correct position (top nipple - run in controlled position). 12. Note & record P/U weight prior to sitting down in nipple. 13. Lightly jar down to seat packing and continue jarring to sheer top pin in running tool. A. Once top pin is sheered, do a pull test min 500# over P/U weight. Proceed to sheer lower pin on running tool by jarring up, which will release running tool from K -Valve assembly, also pulling the XO EQ device on seat. 14. POOH, inspect running tool. 15. RD SSV remote control in HES e-line unit and return control to Badami Control Room Board Operator 16. Notify BP well is ready to put back on production and to pump a 3 -Bbl neat methanol spear down IA before doing so! 17. RDMO Slickline Unit. 18. Inspect job site. Clean up as necessary. Date 03/31/2011 By: Erik Opstad Schlumberger Flowing Pressure Survey Well: Badami B1 -11A Date: DD- MMM -YY 160 - — 2000 — 1800 140 - 1600 120 — 1400• ii, 100 ♦ i — 1200 a 10 Min Stop 103.39 f 10 Min Stop a co 80 @ surface @ surface 1000 E' f' /7---\ ' ' — 800 a , \ 1— � ( 780 12 57.61 \ i s — 600 40 � (( .' , 1 39.54 400 444 92 36.4 20 `L_ R MD 10155' 3990' 2212' 400 75 ------ — 200 • `` 4 . 973 193 4 205.81k 0 0 .0 . am ( j.3�. ( 0 ©� 0 am .�!I) .h0 ne P) .<0 d � ( O � � so O ff ` , n ) 50 .C 0 r l, n3 ti .3 .0 0 r 1. ) o hc .q, .3 � ( C7 O � O ( O .∎'b*IC _a'`* Q ` . 6 &*.< *4 �.0 \ �.' ` - c - .c' - .< 4 ) . 4 ) - 4 .0 (1` - 0 - �'` © o' b; *h �- go co CD- b.ro'1.1.1 -'1 '1 RS( 2b cD.(ID- �� Time Temp (DegF) Pressure (PSI) • 1- ALLIELJ T"C IM Savant Alaska Badami B1 -11A North Slope, Alaska eFlow Program Prepared For: Erik Opstad Date: April 1, 2011 Version: 2.0.26 Submitted by: Dan Brown r- 4p►LLrc L r QPJ • • HALLIBURTON eFlow Client Name: Savant Alaska Well Name: B1 -11A Client Representative: Erik Opstad Field Name: Badami PURPOSE: This Ambient Valve report is to assist in setting the surface dome pressure for type H and K safety valve. The program will calculate a setting dome pressure by correcting for the difference between setting temperature and operating temperature. PROJECT: Region : North America Location : North Slope Area : Alaska Date : April 1, 2011 Comments: Closing pressure at K -Valve = 400psi AMBIENT VALVE RESULTS ' The Surface Setting Pressure is 333 psi .� } Desired Closing Pressure 400 psi This report is based on sound engineering practices, but because of variable well conditions and other information which must be relied upon, Halliburton makes no warranty, expressed or implied, as to the accuracy of the data or of any calculations or opinions expressed herein. You agree that Halliburton shall not be liable for any loss of damage, whether due to negligence or otherwise arising out of or in connection with such data, calculations or opinions. eFlowReport.doc Page 1 April 1, 2011 • • HALLIBURTON eFlaw Client Name: Savant Alaska Well Name: B1 -11A Client Representative: Erik Opstad Field Name: Badami AMBIENT VALVE INPUTS SG Nitrogen 0.970 CHARGING GAS Surface Setting Temp. 60.000 °F Estimated Flowing Temp. at Valve 40.000 °F Old Material Number 22KX38122 WELL INFO Desired Closing Pressure at Valve 400.000 psi eFlowReport.doc Page 2 April 1, 2011 . ! !9212 • SAY T r ALASKA Phone: 907-345-8521 0 RECEIVED' April 1, 2011 \pp 201 Mr. Dan Seamount, Commissioner Alaska Oil & Gas Conservation Commission Gas Cog, Cansitission 333 West 7th Avenue, Suite 100 ` r£ °or gc Anchorage, Alaska 99501 Re: Submittal of Form 10 -403 — Application for Sundry Approvals for K -Valve Installation in Badami Well B1 -11A. Dear Mr. Seamount: After reestablishing production from Badami B1 -11A last month, Savant intends to conduct Sundry operations to install a K -Valve type subsurface safety valve in the well per AOGCC regulations. To that end, we are herewith submitting our Application for Sundry Approvals in connection with that proposed work. Please call me at (907) 868 -1258 should the AOGCC need any additional supporting materials for this application or wish to discuss any aspects of this submittal. Sincerely, SAVANT ALASKA, LLC Erik A. Opstad, General Manager Submitted in Duplicate Cc: Greg Vigil, SALLC SALLC B1 -11A File BPXA Well Files STATE OF ALASKA - .�...0. / ' ALASKAIDAND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: WAIVER . 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development El Exploratory ❑ 198 -0340 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API i mber: Anchorage, AK 99519 -6612 50- 029 - 22829 -01 -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: ❑ B1 -11A Spacing Exception Required? Yes ❑ No 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 367006 BADA -'Field / BADAMI 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): 13375 10474.89 13288 10409.85 NONE NONE Casing Length Size M � TVD Burst Collapse Structural Conductor 74 20" SURFAC- SURFACE 110 Surface 5025 13 -3/8" 68# L -80 S - F' a 51; • SURFACE 4534 4930 2270 Production 10573 7" 29# P -110 U' Ar 0605 SURFACE 8484 11220 8510 Liner 2945 4 -1/2" 12.6# L -80 ' 04 1 el 13325 8353 10475 8430 7500 Liner 4 \ Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 ubing ze: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 1 4 -1/ 12. L -80 SURFACE 10324 r Packers and SSSV Tvoe: 7" X 4 -1/2" HES TNT P K - r( � Packers and SSSV MD and TVD (ft): 10274 8240 12. Attachments: Description Su i• • ; oposal al 13. Well Class after proposed work: Detailed Operations Program ❑ - j ketch ❑ Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/17/2011 Oil eg Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoin • s true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Mark Sauve Title PE Signature / Phone Date 564 -4660 3/17/2011 Prepared by Joe Lastufka 564-4091 COMMISSION USE ONLY ('�' Conditions of approval: ■ otify Commission so that a representative may witness Sundry Number: 311 .� Y U z ✓ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED Other: MAR 17 2011 A MAR 2 2 2011 Alaska Oil & Gas Cons. Commission Subsequent Form Required: hcnoragt APPROVED BY Approved by: 1IRDMS MAR 2 2 211 COMMISSIONER THE COMMISSION Date: MAR iii / ir, Form 10 -403 Revised 1/2010 + Submit in Duplicate B1 -11A 198 -034 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base B1 -11A 8/8/98 PER 13,206. 13,226. 10,348.97 10,363.78 B1 -11A 8/8/98 PER 13,226. 13,246. 10,363.78 10,378.61 B1 -11A 10/29/98 APF 12,606. 12,626. 9,925.26 9,938.9 B1 -11A 10/29/98 APF 12,626. 12,646. 9,938.9 9,952.57 B1 -11A 10/29/98 APF 12,646. 12,666. 9,952.57 9,966.25 B1 -11A 10/29/98 APF 12,676. 12,696. 9,973.1 9,986.79 B1 -11A 10/29/98 APF 12,696. 12,716. 9,986.79 10,000.5 B1 -11A 10/29/98 APF 12,716. 12,736. 10,000.5 10,014.23 B1 -11A 10/29/98 APF 12,736. 12,746. 10,014.23 10,021.11 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • bp 0 Badami B1 -11A Waiver request March 17, 2011 Badami producing well B1 -11A was brought on line on gas lift on March 4 and production has now stabilized. It is producing approximately 183 bopd, 0 bwpd and 3149 mcfd formation gas while using 2563 mcfd of lift gas. The well is not equipped with equipment to set a surface controlled subsurface safety valve. However, it is equipped with a X nipple at 2207' suitable to set a K -valve type SSSV. BPXA requests a waiver from the requirements of 20 AAC 25.265 to continue to produce the well for up to one month without a functional SSSV to provide time to do the following work: - run a down hole pressure /temperature survey to determine proper design conditions - for a K -valve - complete the K -valve design and submit it to AOGCC for approval _ - install the approved K -valve in the well. - All active Badami wells including B1 -11A are equipped with functional surface safety valve systems. The wells are located in close proximity to the processing facility which is manned 24 hours a day. TREE = „- . 4- 1/16" / 5000 PSI / CIW III ? WELLHEAD = 13 -5/8" / 10000 PSI /FMC R SAFETY: WELL REQUIRES A SSSV. = V KB. ELEV = 53.9' . BF. ELEV = 18.6' KOP = 1 I 2207' H 4 -1/2" HES X NIP, ID = 3.813" I Max Angle = 49 @ 12251' Datum MD = I 3990 ( — I " HES DWP, ID = " Datum TV D = L 4000 I--I HOLES 4 -1/2 IN TBG FOR GAS 1.910 LIFT I L GAS LIFT MANDRELS (POGLMS) 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" H 5059' 1 — A ST MD 4 WD DEV TYPE VLV LATCH PORT DATE 2* 4000 3801 43 POGLM DOME BK 16 04/02/02 1* 10155 8154 44 POGLM_ SO BK 20 04/02/02 *POGLM WITH GL MANDRELS n = 10145' " 4- 112 HES DWP,ID= 1.910" Minimum ID 1.875 @ 10316' _� 1 I� 1 2 -3/8" X NIPPLE REDUCER 1 1 10155' I— {HOLES IN TBG FOR GAS LIFT Z S I 10274' j-J 7" X 4 -112" HES TNT PKR, ID = 3.850" I III I 10291' H4 -1/2" X NIP, ID = 3.813" I IN 1 10312' , - 1/2" XN NIP, ID = 3.725" ( 10316' I- 4 -1/2" X 2 -3/8" NIP REDUCER. ID = 1.875" (03/29/10) 4 -1/2" TBG, 12.6 #, L -80 NSCT, --I 10324' I , , - 10324' 1— I4 -1/2" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" H ELMD TT NOT LOGGED I ® I 10430' I X 4 -1/2" LNR HNGR PKR, ID = 4.438" I 17" LNR, 29 #, P110 BTC, ID = 6.184" 1-1 10605' 1 A I. PERFORATION SUMMARY REF LOG: SBT ON 04/05/98 I ANGLE AT TOP PERF: 47 @ 12606' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 12606 - 12666 0 10/31/98 I 12676 - 12746 0 10/31/98 13206 - 13246 FRAC'D 08/08/98 1 I PBTD I--I 13288' I •••••• 4 -1/2" LNR, 12.6 #, L -80 BTC MOD --I 13375' 1.1A1A.Ati. .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS BADAMI ? ? ?? ORIGINAL COMPLETION 02/09/08 RCT /PJC SET BPV (02/04/08) WELL: B1 -11A 03/01/98 DDW SIDETRACK (B1 -11A) 02/09/08 PJC LOCATION CORRECTION PERMIT No: 1980340 03/30/99 JTP UPDATE INFORMATION 03/29/10 CJN/PJC PULL BPV (01/28/08 API No: 50- 029 - 22829 -01 04/01/02 MAS ADD POGLMS 03/29/10 GTW /PJC PULL XX PLUG & RESET NIP REDUCER SEC 8, T9N, R20E, 1426' FNL & 156' FEL 08/30/06 WRR/TLH FORMAT CORRECTIONS 02/21/11 MB /JMD ADDED SSSV SAFETY NOTE 09/03/07 SWC/PJC SET XX PLUG @ 10312' BP Exploration (Alaska) SSSV in Badami Well B1 -11 • Page 1 of 2 • Schwartz, Guy L (DOA) From: AK, OPS END OIM [AKOPSENDOIM @bp.com] Sent: Wednesday, March 16, 2011 5:02 PM To: Regg, James B (DOA) Cc: AK, OPS BAD Facility & Field O &M TL; Herring, Gary D; Erik Opstad; DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA); AK, OPS Gas Lift Engr; Lastufka, Joseph N (SAIC) Subject: RE: SSSV in Badami Well B1 -11 J7-D ra _ 034 Jim Thanks for the reply, I wanted to give you an up -date on this, we are working on the the Sundry to comply with the Application process to flow the well without the SSSV in the well for a couple weeks. Hope to get that to you tomorrow. We are working on the design for the K -Valve and have decided that to get a good design we are going to run a wireline Pressure and Temperature Survey. We hope to have that completed next week and install the K- Valve the week after that. You should be hearing from us soon. Thanks Bruce W Robinson Endicott / Badami OIM 907 - 659 -6555 (ph) 907 - 659 -6799 + 121 ( North Slope Pager) Alternate - Gary Herring Administrative Assistant - Pam / Vanessa; 907 - 659 -6524 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, March 15, 2011 9:41 AM To: AK, OPS END OIM Cc: AK, OPS BAD Facility & Field O &M TL; Herring, Gary D; Erik Opstad; DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: SSSV in Badami Well Bi -11 Need to follow Industry Guidance Bulletin 10 -004 regarding approval for use of K- valve. Refer to top of page 2, Subsurface Controlled Subsurface Safety Valves Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: AK, OPS END OIM [mailto:AKOPSENDOIM @bp.com] Sent: Monday, March 14, 2011 6:12 PM To: Regg, James B (DOA) Cc: AK, OPS BAD Facility & Field O &M TL; Herring, Gary D; Erik Opstad Subject: SSSV in Badami Well B1 -11 Jim Out at Badami Well B1 -11, When we started up in November we made an attempt to flow the well and were not successful. On March 4th we were able to get it on line. We got documented tests of the SSV and the 3/21/2011 SSSV in Badami Well B1 -11 Page 2 of 2 • pressure switch. The issue we have is this well has never had a SSSV in it and it does not have control lines ran to the SSSV nipple, it does have a landing nipple. Our plan is to run a K -Valve type SSSV in the well. We are working now to determine the set point for the K- Valve. At this time I do not think we are going to be able to get the K -Valve set prior to our 14 day window running out. We would like to ask for an extension to continue to flow the well and keep in warm until we can get it set. We do not expect this to take any longer than three weeks. With this all said we would like the extension to be until April 4th 2011, to have the K -Valve set and tested? Please let us know if you have any questions. Thanks Bruce W Robinson BP Endicott / Badami OIM 907 - 659 -6555 (ph) 907 - 659 -6799 + 121 ( North Slope Pager) Alternate - Gary Herring Administrative Assistant - Pam / Vanessa; 907 - 659 -6524 3/21/2011 Approval to continue to operate we B 1 -11 A • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, March 21, 2011 1:35 PM To: 'Sauve, Mark A'; Maunder, Thomas E (DOA) Cc: AK, OPS END OIM; Lastufka, Joseph N (SAIC); Burnworth, Dale A; Regg, James B (DOA); eopstad @gci.net Subject: RE: Approval to continue to operate well B1 -1 IA 19? - 034 Mark, I received the 403 sundry request for a Time Wavier today. Email approval is all that is required to flow the well to gather the needed parameters for the K -valve design. You have until April 4 to flow the well for data gathering and have a K -Valve physically installed. Once needed flow and setup data in hand please submit another 403 sundry for the installation of the K -valve as outlined in the guidance bulletin No. 06 -04. I am returning the current sundry as not needed. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Sauve, Mark A [mailto:Mark.Sauve @bp.com] Sent: Thursday, March 17, 2011 3:59 PM To: Maunder, Thomas E (DOA) Cc: AK, OPS END OIM; Lastufka, Joseph N (SAIC); Burnworth, Dale A; Regg, James B (DOA); Schwartz, Guy L (DOA); eopstad @gci.net Subject: RE: Approval to continue to operate well B1 -11A Tom, Thank you for the approval to continue to operate B1 -11A. The latest test data I have for B1 - 11A was collected yesterday, on March 16, 2011. Here it is: Oil rate: 183 bpd Water rate: 0 bpd Formation Gas rate: 3,149 mscfd Lift gas rate: 2,563 mscfd Well head temp: 83F Well head pressure: 192 psig Mark Sauve Northstar Production Engineer BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907 - 564 -4660 Work Fax #: 907 -564 -4440 Cell Ph #: 907 - 748 -2865 E -mail: sauvema @bp.com 3/21/2011 Approval to continue to operate well B1-11A Page 2 of 2 • From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, March 17, 2011 3:46 PM To: Sauve, Mark A Cc: AK, OPS END OIM; Lastufka, Joseph N (SAIC); Burnworth, Dale A; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: Approval to continue to operate well B1 -11A Mark, It is acceptable to keep the well in operation pending Jim's review of the document. If you would, please provide present pressure, temperature and flow rate values for the well. Tom Maunder, PE AOGCC From: Sauve, Mark A [mailto: Mark.Sauve @bp.com] Sent: Thursday, March 17, 2011 3:25 PM To: Maunder, Thomas E (DOA) Cc: AK, OPS END OIM; Lastufka, Joseph N (SAIC); Burnworth, Dale A; Regg, James B (DOA) Subject: Approval to continue to operate well B1 -11A Tom, As per our previous phone conversation I respectfully request approval to continue to operate Badami producer B1 -11A without a SSSV through March 18, 2011 while the official 10-403 application for continued operation is being processed by the AOGCC. B1 -11A has proven to be susceptible to tubing hydrate formation when shut -in and we would very much like to avoid this potential problem until Jim Regg can review our application. I have been assured that the 10 -403 in question will be hand carried to your offices by courier before 4:00 PM this day. Thanking you in advance, Mark Sauve Northstar Production Engineer BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907- 564 -4660 Work Fax #: 907-564-4440 Cell Ph #: 907- 748 -2865 E -mail: sauvema@bp.com 3/21/2011 SSSV in Badami Well B1 -11 Page 1 of 1 Regg, James B (DOA) PT1, l q —034- From: Regg, James B (DOA) Sent: Tuesday, March 15, 2011 9:41 AM d5 l 11 To: 'AK, OPS END OIM' Cc: AK, OPS BAD Facility & Field O &M TL; Herring, Gary D; Erik Opstad; DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: SSSV in Badami Well B1 -11,4 Attachments: 10- 004.pdf Need to follow Industry Guidance Bulletin 10 -004 regarding approval for use of K- valve. Refer to top of page 2, Subsurface Controlled Subsurface Safety Valves Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 ryry 907 -793 -1236 : a Ai ED M AR 1 8 L O From: AK, OPS END OIM [mailto:AKOPSENDOIM ©bp.com] Sent: Monday, March 14, 2011 6:12 PM To: Regg, James B (DOA) Cc: AK, OPS BAD Facility & Field O &M TL; Herring, Gary D; Erik Opstad Subject: SSSV in Badami Well BSS 01- ►t,a, Jim PSI -1(e r Out at Badami Well, When we started up in November we made an attempt to flow the well and were not successful. On March 4th we were able to get it on line. We got documented tests of the SSV and the pressure switch. The issue we have is this well has never had a SSSV in it and it does not have control lines ran to the SSSV nipple, it does have a landing nipple. Our plan is to run a K -Valve type SSSV in the well. We are working now to determine the set point for the K- Valve. At this time I do not think we are going to be able to get the K -Valve set prior to our 14 day window running out. We would like to ask for an extension to continue to flow the well and keep in warm until we can get it set. We do not expect this to take any longer than three weeks. With this all said we would like the extension to be until April 4th 2011, to have the K -Valve set and tested? Please let us know if you have any questions. Thanks Bruce W Robinson BP Endicott / Badami OIM 907 - 659 -6555 (ph) 907 - 659 -6799 + 121 (North Slope Pager) Alternate - Gary Herring Administrative Assistant - Pam / Vanessa; 907- 659 -6524 3/15/2011 Page 1 oil I Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, October 28, 2010 10:25 AM �l ��� �T10 /TV 03 - 3 't To: 'Erik Opstad' Subject: RE: K- Vavles Installation at Badami 2- �' 1�T0 l '17—/7Y Erik, Installation of valves requires a 403 sundry approval. By CO (Conservation Order) 402B all Badami wells that are capable of flow to surface require a subsurface Safety Valve. There is a guideline bulletin link I will send you that outlines the subsurface K valve requirements.. No. 06 -04. 1 will also give you a link to the CO 402B you should be familiar with. hftD://doa.alaska.ggylpgq/oplletins/builetind-ex.html hftD://doa.alaska.gqv/ogc/orders/co/co400 499/co402b.pdf NOV q 4 20110 Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Erik Opstad ( mailto :Erik.Opstad @savantalaska.com] Sent: Thursday, October 28, 2010 10:00 AM To: Schwartz, Guy L (DOA) Subject: K- Vavles Installation at Badami Guy: As we discussed this morning, Savant will be installing K- Valves in two (2) wells at Badami after start up. These are B1 -11A & 131 -21. A third well, 131 -15, may also need one. B1 -15 has control lines for a conventional surface controlled subsurface safety valve ( SCSSSV), but both are plugged. We're hoping that once the well warms up the lines will clear and we'll be able to wireline set a standard SCSSSV (BBE or other from our inventory), but that may not happen. If the lines cannot be cieared, we'll set a K -Valve in B1 -15 as well. Thanks, Erik S A T ANT ALASKA - Erik Opstad, General Manager 10/ 28/2010 • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, March 12, 2009 8:46 AM To: 'Erik Opstad' Subject: RE: B1-11A (198-034) Erik, Thanks for the information. One item, since it is not your intent to permanently abandon the existing penetration (B1-11A) your new penetration will be a lateral rather than a redrill. The proper name according to our protocol will be B-11AL1. Cail or message with any questions. Tom Maunder, PE AOGCC From: eopstad@gci.net [mailto:eopstad@gci.net] On Behalf Of Erik Opstad Sent: Wednesday, March 11, 2009 6:08 PM To: Maunder, Thomas E (DOA) Subject: RE: Bl-11A (198-034) ~~~~y~~l~'~1 A~ ~, ,~ ~~~~` Tom: 1. Proposed BOP test pressure to be 3500psi. 2. The most recent SITP was 2745 psi taken in conjunction with the start of the latest warm shutdown. 3. Related to tubing plug: The intention was not to make any attempt to WL retrieve this plug. The packer would be milled out and this plug would be retrieved in place when the milled packer 8~ tailpipe assembly are recovered. 4. The recovered 4 '/z" tubing could be used to run back open ended in well to approx. 2200' & left in place until return in 2010 for further well work. 5. The installed ~~temporary" inflatable bridge plug (IBP) would be left in well until such future time as we wish to place the 1-11A leg onto production. 6. Operations Planned for 2010: a) Put rig on hole b) Pull 4 '/2" tubing left as kill string c) Set whipstock at 9300' & mill window in 7" casing. d) Directionally drill 6 1/8" sidetrack hole for B1-11B lateral leg e) Run slotted liner f) Run 3'/2" completion tubing string. B1-11B lateral leg would be produced through a sliding sleeve with 3 '/2" tubing tail & PB stinger extending to & stung into top of existing B1-11A 4 '/Z" liner. At such 3/12/2009 Page 2 of 2 future time as we wish to place the B1-11A leg on production, then the IBP previously set in B1-11A liner at approx. 12,500' would be either SL or CT retrieved up through the 3 '/2"tubing allowing both the B1- 11A 8~ B legs to be comingled or produced separately as desired. Let me know if you have any more questions. Erik From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, March 09, 2009 11:26 AM To: Erik Opstad Subject: B1-11A (198-034) Erik, I am reviewing the sundry for the workover on this well. A couple of items. 1. What is the proposed BOP test pressure? Do you have information on SITP? I see there is tubing plug in the well. 2. A kill string should be left in the well, -2200' as that is your intended freeze protection depth. 3. You list setting a "temporary bridge plug". I presume that will be pulled to do the drilling work? Would you provide some general comments as to what drilling work is planned? Thanks in advance. Tom Maunder, PE AOGCC 3/12/2009 P l~' ~'~ I~ I", 1 Y( ~dl ~ ~ ri > ALASSA OIL A1~TD GAS CO1~T5ER'QATIOAT COl-II~IISSIOI~T Erik Opstad Savant Alaska LLC i SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 2212 Anchorage AK 99511-2212 ~~~ c~~~ Re: Badami Field, Badami Oil Pool, B 1-11A Sundry Number: 309-089 1 ~ 4,~ MAC ~ ~~~ '~ iru~~'e:i7 Ne.k..wJ Dear Mr. Opstad: 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, ~~~~~~ Daniel T. Seamount, Jr. Chair DATED this ~ ~ day of March, 2009 Encl. ~~~ANT ALASKA Anchorage Office vant Alaska, LLG . Box 2212 Anchorage, Alaska 99511-2212 Phone: 907-345-6346 Fax 907-345-8529 Denver Office • Savant Alaska, LLC 730 17th Street, Suite 410 Denver, CQ 80202-3510 Phone: 303-592-1905 Fax 303-592-9909 March 2, 2009 Mr. Dan Seamount, Commissioner Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Submittal of Form 10-403 -Applications for Sundry Approvals on 61-11A Dear Mr. Seamount: Following drilling of the Kekiktuk grassroots exploration well from the B1-38 conductor at Badami, Savant intends to conduct Sundry workover operations on B1-11A to clean up the well and prepare it for a horizontal sidetrack either this summer or during the next winter drilling season depending on the availability of equipment. Following on that plan, we are herewith submitting our B1-11A Application for Sundry Approvals. Savant will be submitting a Permit to Drill application for the subsequent sidetrack operations at a later date. Please call me at (907) 345-6346 should the AOGCC need any additional supporting materials for this application or wish to discuss any aspects of this submittal. Sincerely, SAVANT ALASKA, LLC Erik A. Opstad, General Manager Submitted in Duplicate Cc: Greg Vigil, SALLC Gary Hammon, SALLC • '" STATE OF ALASKA ` ~~~I.~D~ ALA OIL AND GAS CONSERVATION COMM~N ~o~ 3 APPLICATION FOR SUNDRY APPROVALS Z.~w 20 A,4C 25.280 ~d~" s ~~'/~a 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Savant Alaska LLC Development 0 , Exploratory ^ 198-034 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P O Box 2212 `Anchorage, AK. 99511-2212 50-029-22829-01 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ B1-11A 9. Property Designation: 10. KB Elevation (ft}: 11. Field/Pool(s): 367011 - 53.9'- Badami Field/Badami Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD {ft): Effective Depth MD (ft}: Effective Depth TVD (ft}: Plugs (measured): Junk (measured): 13375' - 10475' - 13149' 10307 N/A Fitii; '~.22~1' Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 110' 110' 153D 520 Surface 5025' 9 5!8" 5059' 4534' 5750 3090 Intermediate 10573' 7" 10606' 8484' 11220 8510 Production Liner 2944' 41/2" 10430'-13375' 10475' 7780 6350 Perforation Depth MD {ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3 intervals 12606 thru 13246 9925 thru 10379 4 1/2" 12.6# L-80 10324 Packers & SSSV Type: 4 1/2" HES "x" nipple Packers and SSSV MD {ft): 7' x 4 112" HES TNT Pkr. Pkr. 10274 SSSV 2207 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development Q - Service ^ 15. Estimated Date for 4/10/2009 16. Well Status after proposed work: Commencing Operations: Oil Q ° Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. .Contact Erik Opstad or Gary Hammon Printed Name Erik Opstad ~ , "" Title Alaska Manager Signature Phone 345~34fi l 244-5210 Date 3/2/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ Plu Inte ri g g ty ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Tt~ Other: ~ , .r ~ a~rl~R ~ ~ ~~~5 3"a®C7 S~ ~-~cs..~..`~cs~r ~~~©C~Si r'~~r`~rv~a o.r^NJ~c,.~ ~tC ~~sdc~ ~~ ~~ ~~n~, ~o~nrnissioat Anchof'sge Subsequent Form Rewired: L`® ~„_` ~, ~\ e_~ ~ ~ ~~ ~ ~( ~ APPROVED BY ~ ~ , ~ ~ ~~~~ ~ Approved b : COMMISSIONER THE COMMISSION Date: SAVANT ALASKA Anchorage Office vant Alaska, LLC ~. Box 2212 Anchorage, Alaska 99511-2212 Phone: 907-345-6346 Fax' 907-345-8.521 Denver Office • Savant Alaska, LLC 730 17`x' Street, Suite 410 Denver, CO 80202-3510 Phone: 303-592-1905 Fax 303-592-1909 Workover Well Plan Summary for B1-11A (In Preparation for Future Lateral Sidetrack) 1. MIRU Doyon 16 2. Kill well. NU BOPE & test. 3. Retrieve 4 %" production tubing & mill out packer. 4. Cleanout existing 4'/2" liner to top of fish at 13231'. 5. Set temporary bridge plug at approx. 12500'. Test BP to 3000psi. 6. Leave well with completion fluid to 2200' & freeze protect with diesel to surface. Doyon-16 BOP Sketch ~.,~ . T ~ T~PjrINMGED T&3P ~9t '8!'@ ~,~ fOKE _vES Al?AL'.I~€p TC5 +IQ/R '. 5fi~G -5. ta` MRL G4~ERi±~C1R5. [f~NC~++S~~kJ.R HAIL ~~f5 f'JM SC41rv ~ ~~. ~9` 1ARL Cf'EliISs9~, ~3JL I A".i:f TREE=,.; ~ ~ 4-1/16" / 5000 PSI / CM/ W LHEAD = 13-5/8" / 10000 PSI /FMC A C.TUATOR = KB. ELEV = - BF. ELEV - 53.9' _ .... __ 18 l KOP= _ _. Max Angle = 49 @ 12251' Datum MD = DatumTVD= _ Minimum ID =1.875" @ 10316' 2-3/8" X REDUCING NIPPLE 4-1/2" TBG, 12.6#, L-80 NSCT, I 10324' .0152 bpf, ID = 3.958" 7" LNR, 29#, P110 BTC, ID = 6.184" ~--~ 10605' PERFORATION SUMMARY REF LOG: SBT ON 04/05(98 ANGLE AT TOP PERF: 47 @ 12606' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 12606 - 12666 C 10/31 /98 12676 - 12746 C 10/31 /98 13206 - 13246 FRAUD 08/08/98 PBTD 4-1/2" LNR, 12.6#, L-80 BTC MOD .0152 bpf, ID = 3.958" I 13288' 1 B1-11 A NOTES: J-i BPV (SET 02104/08) 2207' 4-1 /2" HES X NIP, ID = 3.813" 3990' 4-1/2" HES DWP, ID = 1.910" 4000' HOLES IN TBG FOR GAS LIFT GAS LIFT MANDRELS (POGLMSI ST MD TVD DEV TYPE VLV LATCH PORT DATE 2* 1* 4000 10155 POGLM POGLM DOME SO BK BK 16 20 "POGLM WITH GL MANDRELS 10145' 4-112" HES DWP, ID = 1.910" 10155' HOLES IN TBG FOR GAS LIFT 10274' ~ 7" X 4-1 /2" HES TNT PKR, ID = 3.850" I 10291' 4-1 /2" X NIP, ID = 3.813" 10312' 4-1/2" XN NIP, ID = 3.725" 10316' 2-3/8" X REDUCING NIP, ID = 1.875" 10316' 2-3/a" XX PLUG (09/03/07) 10324' 4-1 /2" WLEG, ID = 3.958" F1MD TT NOT LOGGED 10430' 7" X 4-1 /2" LNR HNGR PKR, ID = 4.438" DATE REV BY COMMENTS DATE REV BY COMMENTS ???? ORIGINAL COMPLETION 02/09/08 RCT/PJC SETBPV (02/04/08) 03/Q1/98 DDW SIDETRACK {61-11A) 02/09/08 PJC LOCATION CORRECTION 03/30!99 JTP UPDATE INFORMATION 04/01/02 MAS ADD POGLMS 08/30/06 WRR/TLH FORMAT CORRECTIONS 09/03/07 SWC/PJC SET XX Pl UG @ 10312' BA DA MI WELL: 81-11A PERMff No: 1980340 API No: 50-029-22829-01 SEC 8, T9N, R20E, 1426' FNL & 156' FEL BP Exploration (Alaska) BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 1,2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of July 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 $C;ANNED AUG ~ 1 2002 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: DATE REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. I IA (9-5/8) psi ~DA (13-3/8) psI WHP (psi) Inject 7/1/2002 2250 150 1900 7/2/2002 1350 150 1917 7/3/2002 1600 150 1931 7/4/2002 1200 150 1920 7/5/2002 1200 150 1908 7/6/2002 2800 150 1902 7/7/2002 2200 150 1915 7/8/2002 2300 150 1918 7/9/2002 2300 150 1875 7/10/2002 2300 150 1924 7/11/2002 2300 150 1914 7/12/2002 2300 150 1899 7/13/2002 2300 150 1895 7/14/2002 2300 150 1884 7/15/2002 2300 150 1890 7/16/2002 2200 150 1854 7/17/2002 2300 150 1847 7/18/2002 2300 150 1833 7/19/2002 2200 150 1811 7/20/2002 2250 150 1832 7/21/2002 2250 150 1807 7/22/2002 2200 150 1811 7/23/2002 2200 150 1839 7/24/2002 2200 150 1821 7/25/2002 2150 150 1825 7/26/2002 2250 150 1847 7/27/2002 550 100 1133 7/28/2002 7/29/2002 1700 100 1137 7/30/2002 1750 200 1339 7/31/2002 1750 200 1560 Rate (MBD) WHT (F) 12537 170 14566 173 15952 170 8088 171 16320 170 15974 171 16251 169 16181 171 15040 170 16263 173 16058 170 15832 173 15741 175 15712 172 15855 171 13787 172 15051 175 14713 168 14267 176 14589 168 14148 165 14074 165 14699 160 14183 166 13686 168 14656 167 1419 122 3275 130 4950 157 9860 150 Note Was shut in a short period. WAS S/I FOR WELL WORK Plant S/D Plant S/D $CANNE AU G 1 2D 02 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 7/1/2OO2 7/2/2002 7/3/2OO2 7/4/2002 7/5/2002 7/6/2002 7/7/2002 7/8/2002 7/9/2002 7/10/2002 7/11/2002 7/12/2O02 7/13/2002 7/14/2002 7/15/2O02 7/16/2002 7/17/2002 7/18/2002 7/19/2002 7/20/2002 7/21/2002 7/22/2002 7/23/2002 7/24/2002 7/25/2002 7/26/2002 7/27/2002 7/28/2002 7/29/2002 7/30/2002 7/31/2002 (9-5/8) psi ~A (13-3/8) psI WHP (psi) Inject Rate (MBD) WHT (F) 2250 150 1900 12537 170 1350 150 1917 14566 173 1600 150 1931 15952 170 1200 150 1920 8088 171 1200 150 1908 16320 170 2800 150 1902 15974 171 2200 150 1915 16251 169 2300 150 1918 16181 171 2300 150 1875 15040 170 2300 150 1924 16263 173 2300 150 1914 16058 170 2300 150 1899 15832 173 2300 150 1895 15741 175 2300 150 1884 15712 172 2300 150 1890 15855 171 2200 150 1854 13787 172 2300 150 1847 15051 175 2300 150 1833 14713 168 2200 150 1811 14267 176 2250 150 1832 14589 168 2250 150 1807 14148 165 2200 150 1811 14074 165 2200 150 1839 14699 160 2200 150 1821 14183 166 2150 150 1825 13686 168 2250 150 1847 14656 167 550 100 1133 1419 122 1700 100 1137 3275 130 1750 200 1339 4950 157 1750 200 1560 9860 150 Note Was shut in a short period. WAS S/I FOR WELL WORK Plant S/D Plant S/D STATE OF ALASKA ;:~": ''~ ~' ALASKA OIL AND GAS CONSERVATION COMMISSION ' ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: POGLM Installation Operation shutdown_ Stimulate_ Plugging _ Perforate _ Pull tubing _ Alter casing_ Repair well Other X POGLM Installation '-~. i ,~,, ,~, , ,' -- . 6. Datum e eV~itiod (DF Or KB,feet) ;,,~ ~ :~, ,., RKB 54 feet 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ 4. Location of well at surface 1425' FNL, 156' FEL, Sec. 08, T09N, R20E, UM At top of productive interval 620' FNL, 2340' FEL, Sec. 05, T09N, R20E, UM At effective depth 351' FNL, 2616' FEL, Sec. 05, T09N, R20E, UM At total depth 247' FNL, 2724' FEL, Sec. 05, T09N, R20E, UM (asp's 363856, 5906425) (asp's 361765, 5912549) (asp's 361493, 5912823) (asp's 361386, 5912929) 12. Present well condition summary Total depth: measured true vertical 13375 feet Plugs (measured) 10475 feet 7. Unit or Property name Badami 8. Well number B1-11A 9. Permit number / approval number 198-034 10. APl number 50-029-22829-01 11. Field / Pool Badami Field / Badami Oil Pool TD tag @ 13149' SLM (03/03/2002) Effective depth: measured true vertical Casing Length Conductor 74' Surface 5025' Intermediate 10573' Liner 2944' 13149 feet Junk (measured) 10307 feet Size Cemented Measured Depth 20" 260 sx ArcticSet 110' 9-5/8" 2390 sx PF 'E', 340 sx 5059' Class 'G' 7" 200 sx Class 'G' 10606' 4-1/2" 350 sx Class 'G' 10430' - 13375' True VerticalDepth 110' 4534' 8484' 10475' Perforation depth: measured Open Perfs 12606' - 12666', 12676' - 12746', 13206' - 13246' true vertical Open Perfs 9925' - 9966', 9973' - 10021', 10349' - 10379' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 10274'. 4-1/2", 12.6#, L-80, Tubing Tail @ 10324'. Packers & SSSV (type & measured depth) 7" x 4-1/2" HES TNT Permanent Packer @ 10274'. 4-1/2" HES X Nipple @ 2207' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 02/20/2002 Subsequent to operation 04/09/2002 OiI-Bbl 551 Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl 273 0 925 521 0 Casing Pressure Tubing Pressure 242 241 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoingjs true and correct to the best of my knowledge. ,~~/~~~~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date April 16, 2002 B1-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/02/2002 SBHPS: BRUSH / BROACH 03/03/2002 SBHPS: BRUSH / BROACH 03/03/2002 SBHPS: PARAFFIN / ASPHALTENE REMOVAL 03/04/2002 SBHPS: STATIC BOTTOM HOLE PRESSURE SURVEY 03/28/2002 03/29/2002 O3/29/2OO2 03/30/2002 03/30/2002 O3/3O/2OO2 03/31/2002 04/01/2002 04/01/2002 O4/O2/2OO2 PACK-OFF GAS LIFT MANDREL: DRIFT/TAG; PACK-OFF GAS LIFT MANDREL PACK-OFF GAS LIFT MANDREL: HOT OIL TREATMENT PACK-OFF GAS LIFT MANDREL: DRIFT/TAG; PACK-OFF GAS LIFT MANDREL; PARAFFIN / ASPHALTENE REMOVAL PACK-OFF GAS LIFT MANDREL: LEAK DETECTION LOG PACK-OFF GAS LIFT MANDREL: LEAK DETECTION LOG; PACK-OFF GAS LIFT MANDREL; TUBING PUNCH PACK-OFF GAS LIFT MANDREL: FISH PACK-OFF GAS LIFT MANDREL: FISH PACK-OFF GAS LIFT MANDREL: GAS LIFT--FOR RATE PACK-OFF GAS LIFT MANDREL: PACK-OFF GAS LIFT MANDREL PACK-OFF GAS LIFT MANDREL: GAS LIFT--FOR RATE EVENT SUMMARY 03/02/02 WORK ON CLEANING UP TUBING. 0~0~02 BRUSHED AND FLUSHED TUBING AND TAGGED PBTD @ 13149' SLM WITH A 3.68" CENTRALIZER. WELL LEFT SHUT-IN. 03/03/02 MADE 15 MIN STOP AT 12569' SLM WITH 2.5" CENTRALIZER AND TANDEM SPARTEK GAUGES. O3/O4/O2 MADE 15 MIN STOP AT 12716' SLM, 15 MIN STOP AT 12858' AND A 6 HR STOP AT 12716' SLM WITH TANDEM SPARTEK GAUGES. WELL LEFT SHUT-IN. 03/28/02 RAN 3.25 GAUGE RING W/TEL, TOOLS FALLING REALLY SLOW. WELL SHUT- IN. 03/29/02 PUMP 65 BBLS DIESEL DOWN TBG @ 190'. O3/29/O2 RAN 3.80 GAUGE RING TO "XN" NIPPLE. RAN POGLM DRIFT. SET 4-1/2" X 1.875" NIPPLE REDUCER IN 'XN' NIPPLE. RAN 'X' CK SET, CK SHEARED CONFIRMING A GOOD SET. LEFT WELL SHUT-IN. 03/30/02 BADAMI WELL. LEAK DETECT LOG TO FIND TUBING PUNCH (FOUND AT 4000'). SELECT LOCATION FOR TUBING PUNCH/POGLM SET TO FOLLOW. PUNCH TUBING AT 10154'-10156'. SET A POGLM OVER TUBING PUNCH AT 10154'- 10156'. SET A POGLM OVER TUBING PUNCH AT 4000'. NOTIFY PAD OP & PROD CONTROL OF WELL STATUS: LEFT SHUT IN. Page I B1-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/30/02 PRESSURE UP ON TBG FOR E-LINE. LEAK DETECT LOG AFTER SETTING POGLM. RIH TO 4000' (LOCATION OF UPPER TUBING PUNCH) & FOUND POGLM DID NOT SET. NOTIFY PAD OP OF WELL STATUS: SHUT IN. 03/31/02 RAN POGLM PULLING TOOL & LATCH POGLM THAT FELL DOWN HOLE @ 10,106' SLM (SITTING ON TOP OF BOTTOM POGLM), POOH SLOWLY. RET ENTIRE POGLM. WELL LEFT SHUT-IN. 04/01/2002 SET 1.81 CATCHER SUB IN NIPPLE REDUCER @ 10,296' WLM. PULLED 1" DGLV (BK LATCH) FROM BOTTOM POGLM @ 10,154' SLM. 04/01/02 SET HES 4-1/2" DWP W/GLM , CENTER OF UPPER ELEMENT AT 3995'. CENTER OF LOWER ELEMENT = 4005.4'. DEPTH CORRELATED TO SWS LEAK DETECT LOG DATED 30-MAR-2002. 04/02/02 PULLED 1" BK LATCH DGLV FROM TOP POGLM @ 3988' SLM. SET 1" BK LATCH (16/64 PORT W/2327 PSI TRO) LGLV IN TOP POGLM @ 3988' SLM. SET 1" BK (20/64) OGLV IN BOTTOM POGLM @ 10,154' SLM. PULL CATCHER SUB @ 10,296' SLM. <<<TURNED WELL OVER FOR PRODUCTION>>> Fluids Pumped BBLS 3 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 3 TESTS) 457 DIESEL 46O TOTAL TUBING PUNCHER-PERF 03/30/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 1-11/16" TUBING PUNCHER, 4 SPF, ZERO DEGREE PHASING, LOWER SIDE OF TUBING ORIENTATION. 10154'-10156' Page 2 Well Compliance Report File on Left side of folder 198-034-0 B~~i~ ~/~z~l~l lA 50- 029-22829-01 BP EXPLORATION MD 13375 TVD 10475 Completion Date: 3/2/98 Completed Status: 1WINJ Current: 1-OIL T Name Interval Sent Received T/C/D D 8293 CCL/PLUG SET L GAS LIFT L GR/CCL 5-16 SPERRY GR/EWR4 OH 4/13/98 4/14/98 //~INAL 2160-2760 CH 5 11/9/98 11/9/98 (.~dAL 1000-13046 CH 5 1/14/99 1/21/99 ..~INAL 13070-13250 CH 5 10/5/98 10/6/98 L GR/CCL ~FINAL 3885-4030 L GR/CCL ~-~q~AL 12500-13147 L INJP .-anql~L 11762-11965 10/11/99 L MAC /,~:~AL BL(C~0600-13200 L MAC/GR ~.bFN~L 10535-13255 L NGP/DGPUEWR4-MD t-.-~AL 5075-13375 L NGP/DGR/EWR4-TVD tt~XL 4545-10475 L PROD t.-.t~AL 13070-13294 11/9/98 11/9/98 11/9/98 11/9/98 10/8/99 10/8/99 10/19/98 10/22/98 CH 5 CH 5 CH 5 OH 5 OH 5 OH OH CH 5 CH 5 CH 5 OH L PROD-SP1N/TEM/ F.,EINAL PRES/JWL 1000-13046 L SBT t.~INAL 10422-13256 R MWD SRVY t~-'~RRY 11725.74-13375. Daily Wel!/Ops A/A//~ __. ?/~//c/~ Are Dry Ditch Samples Required, yes Was the well cored? yes ~ Analysis Description ~ no 4/7/98 4/8/98 5/4/98 5/5/98 5/4/98 5/5/98 10/5/98 10/6/98 1/14/99 1/21/99 4/7/98 4/8/98 7/22/98 7/23/98 Comments: Tuesday, April 04, 2000 Page 1 of 1 BP EXPLORATION Memorandum To' Blair Wondzell fm' Anna Dube Re' February 14, 2000 10-404 for Xylene/Diesel Stimulation on Badami B1-11A Blair, Please find attached the 10-404 report for your records for the xylene/diesel stimulation job on Badami Bl-llA which was completed January 25th, Included are a summary of the wellwork with well test information, a copy of the wellwork telex, and a current plot of well test data. If you have any questions on the information provided, please feel free to give me a call. Regards, Anna Dube Petroleum Engineer Eastern North Slope 564-5230 STATE OF ALASKA ALASKA~OIL AND GAS CONSERVATION CO'i~IMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [~ Repair Well [] Other 2. Name of Operator 5. Type of well:, . 6. Datum Elevation (DF or KB) [X:] Developmem KBE = 53.9' BP Exploration (Alaska) Inc. [] Exploratory 7. Unit or Property Name 3. Address []Stratigraphic Badami Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number B1-11A 3854' NSL, 156' WEL, SEC. 08, T09N, R20E, UM 9. Permit Number / Approval No. At top of productive interval 198-034 300-012 4261' NSL, 1974' WEL, sec. 05, T09N, R20E, UM !10. APl Number At effective depth 50-029-22829-01 4993' NSL, 2682' WEL, SEC. 05, T09N, R20E, UM 11. Field and Pool At total depth Badami 5034' NSL, 2742' WEL, SEC. 05, T09N, R20E, UM 12. Present well condition summary Total depth: measured 13375 feet Plugs (measured) true vertical 10475 feet Effective depth: measured 13288 feet Junk (measured) true vertical 10410 feet Casing Length Size Cemented MD TVD Structural Conductor 75' 20" 260 Sx Arcticset (Approx.) 110' 100' Surface 5025' 9-5/8" 2390 sx PF 'E', 340 sx Class 'G' 5059' 4534' Intermediate 105573' 7" 200 sx Class 'G' 10606' 8484' Production 2944' 4-1/2" 350 sx Class 'G' 10431' - 13375' 8354' - 10475' Liner . ~. ~-~ Perforation depth: measured 12606' - 13246' (Nine Intervals) true vertical 9925'- 10379' (Nine Intervals) !:'L~-i~ '~ ~aska 0il" C-a~- Cons. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Anc-hol'8,ge Packers and SSSV (type and measured depth) HES 'TNT Permanent Packer at 10274'; HES 'X' SSSV Landing Nipple at 2207' 13. Stimulation or cement squeeze summary Xylene / Diesel Stimulation 01/25/00 Intervals treated (measured) Treatment description including volumes used and final pressure Bullheaded 18 bbls xylene and 260 bbls diesel to displace tubing and stimulate near wellbore reservoir. Left shut in to soak for two weeks with well head pressure reading 2300 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 42 bopd Subsequent to operation: 759.6 bopd 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Pre-Produced Injector [] Daily Report of Well~erations 17. Iherebycertifythatth!~egoing,strue¢"dlorree~tothebestofmyknowledge Signed AnnaDul~ %/~ PL,, ~ Title Petroleum Engineer, ENS Date Prepared By Name/Number: Anna Dube, ,~64-5~2~0 Form 10-404 Rev. 06/15/88 Submit In Duplicate Summary of Xylene/Diesel Stimulation Wellwork on Bl-11A The xylene/diesel stimulation wellwork on B1-11A was completed .]anuary 25th, 2000. The job consisted of bullheading 18 bbls of xylene followed by 242 bbls of hot diesel to displace the tubing and stimulate the near wellbore reservoir. A pressure decrease was observed after pumping 210 bbls which is believed to be indicative of removal of paraffin and/or asphaltenes in the perforations. An additional 18 bbls of hot diesel was placed in the flowline to remove asphaltene build-up. The well was pressured up with gas lift and left shut-in for approximately two weeks to soak. On January 19TM, BI-:~iA tested at 656 bopd with a gas lift rate of :[.8 mmscfd. Four days later, the well tested at 42 bopd with a gas lift rate of 2.1 mmscfd. This well is a cycle well that tends to fall over at about 600 bopd due to limiting wellbore hydraulics. We believe the well work resulted in an increase in productivity when considering the rates at which the well comes on-line. The well was brought on line on February 7TM and tested at :L374 bopd with a gas lift rate of 2.:[ mmscfd. This is approximately 500 bbls higher than the well has come on during the last three production cycles. It is probable the production cycle will be extended with these higher rates. Below is a summary of the well tests since the well was placed back on production on February 7th, 2000. Data Oil Rate (bopd) Gas Lift Rate (mmscfd) 2/7/00 1372.9 2. 2/8/00 759.6 1.4 2/12/00 791.5 2.1 Badami, ALASKA TO: Anchorage PE's FROM: Jeff Eckstein Well Name: B1-11 Main Category: Stimulation Sub Category: Xylene / Diesel Operation Date: 01/25/00 Date: 01/27/00 Summary Bullheaded 18 bbls of xylene, followed by 242 bbls of hot diesel (180 degrees) down the tubing of well B1-11. Pressure decrease observed after pumping 210 bbls is attributed to improved injectivity due to paraffin / asphaltene cleanup at the perforations. Bullhead operation was followed-up with 18 bbls of hot diesel down the flowline to remove asphaltene build-up. Opened up gas lift to pressure up the well to help drive the diesel down. Well to remain shut-in for 1 to 2 weeks. 01/26/OO HB&R Initial Conditions SIP= 250 IAP=1000 OAP=0 Final Conditions SIP= 2300 lAP=2200 OAP=350 Pre-job safety: Chemical handling and spill prevention. Time Pressure Rate Total Comments (BPM) bbls 1050 4500 - Pressure test hardline. 1053 350 2.1 0 Start pumping xylene down the tubing. 1100 325 2.1 10 1104 400 1.5 18 Xylene pumped off, stop to load diesel. 1223 4500 - 18 Pressure test hardline. 1236 375 1.0 30 Pumping hot diesel (160 degrees) down tubing. 1247 900 1.2 40 Diesel temperature up to 180 degrees. 1301 1650 1.1 60 1311 2200 1.0 70 1323 2500 0.75 80 1334 2550 0.75 88 Shutdown to reload diesel. 1452 4500 - 88 Pressure test hardline. 1453 500 1.0 88 Resume pumping diesel down tubing. 1500 1000 0.90 98 1513 1700 0.80 108 1526 2450 0.70 118 1539 2700 0.60 128 1556 2800 0.50 138 1614 2850 0.50 148 1632 2950 0.50 158 1635 2750 0.40 160 Shutdown to reload diesel. 1801 4700 160 Pressure test hardline. 1802 850 0.60 160 Resume pumping diesel down tubing. 1820 1400 0.50 170 1836 2150 0.50 180 1854 2600 0.50 190 1915 2662 0.44 200 1935 2650 0.49 210 1949 2550 0.49 216 Pressure starting to come down. 2013 2300 0.52 229 Shutdown to reload diesel. 2107 4500 229 Pressure test hardline. 2108 800 0.88 230 Resume pumping diesel down tubing. 2120 1475 0.83 240 2132 2150 0.81 250 2145 2400 0.81 260 Stop pumping down the tubing 2150 250 0.86 261 Start pumping down the flowline. 2200 300 1.3 271 2206 300 1.3 278 Shut down pumping. Rig down HB&R. Fluids Summary Diesel 260 bbls Xylene 18 bbls TOTAL 278 bbls Well Test Plot WELL: Bi-llA/BADAi~I Dates from 09/04/1998 to 02/14/2000 · (.; ) 10000 9000 8000 7000 6000 5000 4000 3000 1998 , ::::::::::::::::::::::: 2000 1000 900 8O0 70O 600 5O0 400 300 200 100 ,_-:::: :,I: -:!::::: ,, ,, 80,,~- - 4>- r ..... , 704 '~..~-.~4>' , ...... 60-'.~- - ~ ....... 50 ~ , 40 -~- 4> ........ 30 .......... M A M ,I ,I A ~ ¢1 N D ,I F 2000 , I I I I I ' I I I ' I ~ 80' 40 20 o! , , , , , ?99 , , , , , ..... ~ ..... , ..... ~ ..... , ..... ~ ..... , ...... , ..... u ..... , ..... ~ ..... , ..... ..... ', ..... ', ..... ~ ..... ', ..... ~ ..... ', ...... ', ..... ~ ..... ',' '1'"~ ..... ', ..... I O N D 1998 , , , i i , i J A $ O 999 S O N D 1998 , - _ . . ZI'~ -_ '1 ' N D J 2000 , , .................... , ........... , ...... , ...... .... , ..... _, ..... , ..... ~ "~-'~ 'L'_ ~'"~-" O' ,-,-,,-,-,-.-,-,,-~ ,-.-. ---.------,.,.-,-, . _--._ _- C ~,-.,~,w.,,~C_,,~ ' '"'~ '"""~ O J F U A ...... M- ...... -0 ...... J A S O N D 1999 J F 2000 WT 11:11:43 February 14 2000 CPE V1.1.25 ---;----JGross Fluid --s---IOil Rate G.O.R. Gas Lift IMan. Pressure IMan. Temp. BP EXPLORATION Memorandum To: Blair Wondzell fm: Anna Dube Re: 10-403 for Stimulation of Badami B1-11a January 18, 2000 Blair, Please find attached the 10-403 application for your approval for stimulating Bl-lla with a diesel wash which we would like to carry out this weekend. We are investigating whether this will improve well performance by removing paraffins from the reservoir in the near well bore region. If you have any questions regarding t'he program please give me a call. :- Regards, Anna Dube Petroleum Engineer Eastern North Slope 564-5230 ;!./-",?'i ! k 9%,n Anchorage STATE OF ALASKA ALASKA'olL AND GAS CONSERVATION CO~vllSSlON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface v,/ 3854' NSL, 156' WEL, SEC. 08, T09N, R20E, UM At top of productive interval 4261' NSL, 1974' WEL, sec. 05, T09N, R20E, UM At effective depth 4993' NSL, 2682' WEL, SEC. 05, T09N, R20E, UM At total depth 5034' NSL, 2742' WEL, SEC. 05, T09N, R20E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic E-]Service 6. Datum Elevation (DF or KB) KBE = 53.9' 7. Unit or Property Name Badami Unit 8. Well Number B1-11A 9. Permit Number 198-034 10. APl Number 50- 029-22829-01 11. Field and Pool Badami 12. Present well condition summary // Total depth: measured 13375 feet true vertical 10475/feet Effective depth: measured 13288 feet true vertical 10410 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 75' 20" 5025' 9-5/8" 105573' 7" 2944' 4-1/2" Plugs (measured) Junk (measured) Cemented 260 Sx Arcticset (Approx.) 2390 sx PF 'E', 340 sx Class 'G' 200 sx Class 'G' 350 sx Class 'G' ORIGINAL MD 110' 5059' 10606' 10431' - 13375' TVD 100' 4534' 8484' 8354' - 10475' Perforation depth: measured true vedical 12606'- 13246' (Nine Intervals) 9925'- 10379' (Nine Intervals) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Packers and SSSV (type and measured depth) HES 'TNT Permanent Packer at 10274'; HES 'X' SSSV Landing Nipple at 2207' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation I 15. Status of well classifications as: January 22, 2000 16. If proposal was verbally approved [~ Oil [] Gas [] Suspended Service Pre-Produced Injector Name of approver Date approved Contact Engineer Name/Number: ('"'~nna Dube, 564-5230 Prepared By Name/Number: Anna Dube, 564-5230 17' I hereby certifY that thl'f°r~~s tru~'d c°rrect t° the best °f mY kn°wledgeBill Turnbu,I Signed _~~ Title Senior Petroleum Engineer, ENS Date _ I _ _ Commission Use Only ! Conditions of Approval: Notil 3~mmission so representative may witness I Approval No.,.~~ / Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test~ Subsequent form required~l~¥~'{~L'lk ORIGINAL SIGNED-BY A,, ye_.___.,,, Approved by order of the Commission Robert N. Christerls0rl C o.o.o.o.o.o.o.o.o.~mlsslo n e r Form 10-403 Rev. 06/15/88 ~ ,, i,'),-~v~ Date /"-"c~/~(~ ~) submit In Triplicate BP EXPLORATION Memorandum To: J. Powers/J. Eckstein January 18, 2000 fm: A. Dube Re: Stimulation of Well B1-1 la Please run a diesel stimulation job on Badami well B1-11A. The objective of this job is to improve productivity by dissolving paraffin and asphaltenes in the near wellbore section of the reservoir. B1-1 lA has become a cycle well, producing well for approximately a month and then falling off. Leaving the well shut-in for more than two weeks allows the well to heal as it comes back on-line at higher rates. It would be opportune to run this job when production begins to fall off and allow the diesel to soak during the shut-in period. Please displace the tubing with approximately 200 bbls of diesel and then add another 60 bbls (approximately one truck load) to stimulate the near wellbore reservoir. Any questions or comments may be directed to Anna Dube (x5230). xc: B1-1 la Well File IVED dAr,j 1 8 2000 B1-11A · Zone AS, J1 & J2 pre-producer injector. · Cycle Well - Currently producing. · Holes in tubing for gas lift @ 3990' MD. . .c..u..m.u.~.a..ti.v..e..(M...b..b.a.s.. p. r..M.M...S..C...F.), t.h.r.u...1, p./..6./..9..9..-. Total Oil 294.0 Water 0 Gas 113.6 . .C..o..m..p.l.e..tj.o..n...D..a..t.a.; Tubing Tail Pipe-Tubing Liner Perforations Last TD Simple Single Packer 4~1/2" 12.6¢/ft L-80 NSCT 4-1/2" 12.6¢/ft L-80 (min ID 3.725") 4-1/2" 12.6¢/ft L-80 2-3/4" AWS DP Guns, 6 SPF 13,182 WLMD - corrected (10-28-98) ..C..u.r.r.e..n.t..W...e.l!..D.a.t.a.; 10/1/99 (lasttest) RATE CHOKE GOR RATE BS&W WHFP (BOPD) (BEANS) (SCF/STB)(BWPD) (%) (PSIG) APl Gravity 1431 100 70? 0 0 236 26° ..O.p.e.r.a..ti .q.n..a.I..H..igh. !igb. ts.; 3-4-98 8-3-98 8-8-98 8-16-98 8-17-98 8-19-98 9-12-98 9-13-98 10-29-98 11-4-98 12-5-98 12-19-98 12-29-98 04-05-99 04-07-99 04-12-99 04-13-99 Completed Tag TD @ 13,280' MDRKB. Perf 13206-13246' MD with 2-3/4" BH guns. Static: GaUge pressure 5497 psia @ 10312'ft mdbkb, 8213 ft TVDss '-' Reservoir pressure 6411 psia @ 13210 ft mdbkb, 10298 ft TVDss Hydraulic Fracture treatment: 188,000¢ sand behind pipe (frac appeared to be growing out of zone) Post frac clean-out with CTU Aborted add-perf attempt. Drawdown too high. Pressure build-up. K= 80 md, Skin= 0.5. Indications of narrow channel drainage system. Add-perfs in J2 interval 12676-12746' MD and J1 interval 12600'-12666' MD with 6spf 2-3/4 DP guns Punched two holes in tubing at 3990' MD to initiate gas lift. Set DH gauges in XN for PBU #2 Pull DH gauges from XN: no PBU attempted PL. 5% from Jl&J2 95% from A5. FBHP = 2000 psig. Too much loose fill in liner for accurate TD tag. FCC with Coil to 13231 ft md. Tagged fish. Bottom 15 ft of perfs covered. Tagged fill high with slickline. Abandoned fishing attempt. Ice/hydrate plug at 2600 ft, will need coil to remove plug. Removed hydrates with hot oil than FP well to 5000' .C.u.r.r.en.t.B.e.c..o. mme..n.d_ed.....A.c.ti.o..n.; IVED Well Test Plot WELL: BI-llA/BADAMI Dates from 08/28/1998 to 01/17/2000 25 . A S O N D J F M__A__M__J__ J . A__S O__N__ __D J 10000 8000 7000 6000 5000 4000 3000 2000 lOOO 900 800 700 600 500 400 300 200 lOO yu 80 70 60 50 40 30 A $ O N D J F M A M J J A S O N D 1998 1999 24 40 ........ ~ ...................................... , ......... , ......... , ........ , ............. i ....... ~ ........ i ........... , .......... i . . · ~o ;, ' ........ : : ............ i .......... ,' .......... ; , ............ , 1998 1999 2000 10:34:40 January 17 2000 CPE V1.2.03 ~ Gross Fluid --D---- O I Rate -.-. ~ G.O.R. _~ ,. Gas Lift Man. Pressure Man. Temp. Kelly bushing to wellhead (ft) 35.3 Wellhead to sea level (ft) 18.6 J1 J2 A5 Conductor H40 20.000 19.124 91 110 56 0 L-80 NSCT Production Tubing 4.500 3.958 12.6 HES 'X" Safety Valve Landing Nipple 4.500 3.813 2207 2143 3 L-80 Surface Casing 9.625 8.835 40 5059 4480 45 Tubing punch for gas lift 3990 3749 43 - two holes phased 180 degrees apart HES 'TNT' Permanent Packer 5.875 3.958 23-29 10274 8186 44 HES "X' Landing Nipple, 9CR 4.500 3.813 10291 8198 44 HES 'XN" Landing Nipple, 9CR 4.500 3.725 10312 8213 44 Wireline Entry Guide 5.250 3.958 10324 8222 44 7' x 4 1/2' Liner Hanger/Packer 10431 8300 43 Intermediate Casing 7.000 6.1 84 29 10606 8430 41 6spf; 2~A'; Random; 60~ph 12606-12666 9871-9912 47 6spf; 23~4"; Random; 60~ph 12676-12746 9919-9967 47 6spf; 23~'; Random; 60~ph 13206-13246 10295-10325 43 PBTD 13288 10356 42 Production Liner 4.500 3.958 12.6 13375 10421 42 Date Rev by Comments 7/21/1997 B.Turnbull Initial design 9/24/1997 B.Turnbull Removed GL mandrel and X-nipple 6/~7/1,908 B.Turnbull As built dimensions added 8/3/1998 B.Turnbull checked against tally 8/25/~008 B.Turnbull post perfs 11/5/1998 M. Sauve Add-perfs & gas-lift tubing punch added 7/1z/~009 D. Kim Confirmation of fish @ 13231 ft MD BP EXPLORATION, Alaska Date: 01-14-99 Trans# 90151 BADAMI LOG DATA Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name RecType Rec Date Company Code Comments B1-25 CH 29-Dec-98 BAKER GAS LIFT SURVEY, OTHER SERV- SPINNER/TEMP/PRES B1-25 CH 29-Dec-98! BAKER JEWELRY LOG B1-25 CH 29-Dec-98 BAKER SPINNER/TEMP/PRESSURE B1-11A CH 29-Dec-98~ BAKER SPINNER/TEMP/PRESSURE- JEWELRY LOG B1-11A CH 29-Dec-98' BAKER GAS LIFT SURVEY Please sign and return one copy of this transmittal to: Carla H. Mclntosh Petrotechnical Data Center LO(~ DATA AOGCC-1 blueline/1 sepia PETROFINA-1 blueline/1 sepia DNR- 1 blueline BP - - 1 blueline Howard Oakland Mike Engle Tim Ryherd Dave Goodwin MB 7-2 RECEIVED JAN 2.1 1999 AlaskaOil & Gas Cons. Commi~ion Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 6, 1998 Blair E. Wondzell Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska, 99501 Request for Waiver from Production Equipment Rule 20AAC25.200(d) Dear Blair, On 11/4/98 two holes were punched in the 4-1/2" production tubing of well B1-1 la at 3990' MDBKB, establishing tubing-casing annulus communication. The purpose of this action was to initiate gas lift, in the absence of gas-lift mandrels, to B1-1 la in order to improve its production rate. B1-1 la has been on continuous gas lift since this operation and is expected to continue on gas lift into the foreseeable future. BPXA believes that this operation does not jeopardize the casing integrity of the wellbore and as such constitutes a prudent operator action. BP Alaska agrees to monitor the casing pressure in well B1-1 la and take any steps necessary to prevent over pressuring of the tubing-casing annulus. Any change in well status will be directly communicated to the AOGCC. Your concurrence with this action is sought. Please contact Mark Sauve, at 564-5407, if you have any questions or require further clarification. Please indicate your concurrence by signing in the space below and returning a copy of this letter to us by FAX (907-564-418!) or mail. ~" Thank you. Bill Bredar Badami Subsurface Manager Eastern North Slope Asset Group h ? MAS/mas t~OV 0: t998 FAX TRANSMITTAL BP EXPLORATION (ALASKA) .INC. 900 E. BENSON BLVD.~ P. O. BOX 1966~2 ANCHORAGE, AK 99519 ]?I-IONE (907) 564-5797 ~_FAX (907) 504-4181 '- F'o-~. 0ax ..q-6q - FROM: 6ill 6r~. dar' PAGES: DATE: 7~7~ - 7~5 # z COMMENTS: BP EXPLORATION, Alaska Date: 11-9-98 Trans# 89827 BADAMI CASED HOLE LOG DATA Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name RecType Rec Date Company Code Comments B1-1 lA CH 29-Oct-98 ATLAS PFC GAMMA RAY LOG, CASING COLLAR LOCATER B1-1 lA CH 23-Oct-98 ATLAS CASING COLLAR LOCATER, (PLUG SETTING RECORD) B1-1 lA CH 04-Nov-98 ATLAS PFC GAMMA RAY LOG, CASING COLLAR LOCATER Please sign and return one copy of th~~ t_~o: Carla H. Mclntosh Petrotechnical Data Center LOG DATA AOGCC - 1 bluelineJ1 RS Howard Oakland PETROFINA- 1 blueline/1 RS - Mike Engle DNR-1 blueline Tim Rhyherd BP - - 1 blueline Evelyn Raybon RECEIVED ~ O9 1998 Oil & G~ ~. Oo~ Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska .. Date: 10-19-98 Trans# 89696 BADAMI LOG DATA (Color and B&W Logs) Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 ,,ISw Name Rec Date IRecType ICompany Code IComments ~ '~)'~('~1B1-1 lA 27-Mar-geloH IATLAS IMULTIPOLE ARRAY ACOUSTILOG I Please sign and return one copy of this transmittal to: Carla H. Mclntosh Petrotechnical Data Center LDG DATA -~[rOGCC- 1 blueline/1 RS PETROFINA - 1 blueline DNR-1 blueline/1 RS BP -- 1 blueline BP M1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd Evelyn Raybon Ken Lemley RECEIVED OCT ?_? ~998 0il & ~ Cons. Commission Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 10-5-98 Transit 89595 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 SwName Log Type RecDate Company Code Run Num Api Num 89595 B1-14 STATIC 21-Aug-98 ATLAS 4 500292287400 89595 B1-16 STATIC 20-Aug-98 ATLAS I 500292288000 1,4~ 89595 B1-11 PFC 07-Aug-98 ATLAS I 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 bluelineJ1 sepia DNR - 1 blueline BP -- 1 blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh R, ECEtV[. ' OCT 06 199~:' ~1 & Gas C~ns. Co, ...... ~..:,~ Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASKA.-~IL AND GAS CONSERVATION CO~vllSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska)!nc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface [] Operation Shutdown []Stimulate [] Plugging ~'Perforate l--] Pull Tubing I--lAIter Casing [] Repair Well ~_lOther 5. Type of well: 6. Datum Elevation (DF or KB) [] Development KBE = 53.9' [] Exploratory 7. Unit or Property Name [] Stratigraphic Badami ~ ~ervice 3854' NSL, 156' WEL, SEC. 8, T9N, R20E, UM At top of productive interval N/A At effective depth 285' NSL, 254' WEL, SEC. 4, T9N, R4E At total depth 5034' NSL, 2742' WEL, SEC. 5, T9N, R20E, UM 8. Well Number B1-11A 9. Permit Number / Approval No. 98-34 10. APl Number 50-029-22829-01 1. Field and Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 13375' feet 10475' feet 13288' feet 10410' feet Length Size Structural Conductor 74' 20" Surface 5025' 9-5/8" Intermediate 10573' 7" Production Liner 2944' 4-1/2" Plugs (measured) Junk (measured) Cemented MD TVD 260 sx Arctic Set (Approx.) 110' 110' 2390 sx PF 'E', 340 sx Class 'G' 5059' 4534' 200 sx Class 'G' 10606' 8485' 350 sx Class 'G' 10431 '-13375' 8354'-10475' Perforation depth: measured 13206'-13226'; 13226'-13246' true vertical 10349'-10364'; 10364'-10379' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 10324' Packers and SSSV (type and measured depth) Packer @ 10274' SSSV @ 2207' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure RECEIVED SEP 2 9 1998 Alaska 0il & Gas Cons. commission Anchorage 14. Prior to well operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Serv~ Subsequent to operation: 5. Attachments I16. Status of well classifications as: [] Copies of Logs and Surveys run ~_,1~ viler' I~ ("4~ ~ .~u~n~nH~H ..... E~ Daily Report of Well ~>~rations I 7. I hereby c~if~ tha,t/th~/f/re,going i_,;,~tr~, and correct to the best of my knowledge "MICI~A'~L"W~LL~S ~~_J~~ Title Technical Assistant IV Prepared By Name/Number: Date Form 10-404 Rev. 06/15/88 Submit In Duplicate B1-11A DESCRIPTION OF WORK COMPLETED Initial Perforation O8/O8/98 The following initial interval were perforated using 2 3/4" guns, 6 SPF, random orientation and 60° phasing. 13206' - 13226' MD 13226' - 13246' MD 12160'- 12318' MD Kelly bushing to wellhead (ft) Wellhead to sea level (ft) 35.3 :~_ OD~ _-; ~ID-- _We~ht~ -~-~.'--MD ~ ~'~ TVD~ ~D~v'n 18.6 --L Conductor H40 20.000 19.124 91 110 56 0 L-80 NSCT Production Tubing 4.500 3.958 12.6 HES "X" Safety Valve Landing Nipple 4.500 3.813 2207 2143 3 Tubing punch for gas lift 3990 3749 43 - two holes phased 180 degrees apart · L-80 Surface Casing 9.625 8.835 40 5059 4480 45 HES"TNT" Permanent Packer 5.875 3.958 23-29 10274 8186 44 HES "X" Landing Nipple, 9CR 4.500 3.813 10291 8198 44 HES"XN" Landing Nipple, 9CR 4.500 3.725 10312 8213 44 Wireline EntryGuide 5.250 3.958 10324 8222 44 7" x 4 1/2' Liner Hanger / Packer 10431 8300 43 Intermediate Casing 7.000 6.184 29 10606 8430 41 6spf; 2~"; Random; 60~ph 12606-12666 9871-9912 47 6spf; 2~"; Random; 60~ph 12676-12746 9919-9967 47 6spf; 2~,4"; Random; 60~ph 13206-13246 ~0295-10325 43 PBTD 13288 10356 42 Production Liner 4.500 3.958 12.6 13375 10421 42 Date Rev by Comments 7/21/97 B.Turnbull Initial design 9/24/97 B.Turnbull Removed GL mandrel and X-nipple ~7/9a B.Turnbull As built dimensions added 8/3/95 B.Turnbull checked against tally 8/25/98 B.Turnbull post perfs 11/5/98 M. Sauve Add-perfs & gas-lift tubing punch added BI-llA 11-l-98.xls 3:29 PM 11/6/98 J Ub, i ' U~rivi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2, Name of Operator BP Ex, oration (Alaska) Inc, 3, Address P.O.Box 196612, Anchorage, Aldd~a 99~16-6612 · % Location of well at surface 3854' NSL 156' WEL SEC 8, T9N, R20E, UM At top of productive Interval At effective depth At total depth 5034' NSC 2742' WEL SEC 8. TeN, 1~20E, UM i2, Present well condition summaw Total depth: measured 13375 teet true vertical 10475 feet Effective depth; measured 13288 feet true vertlaal 10~tlO feet 5, Type of well: ~-Ddtum E!~vcrllon (DF or KB) ~'-~Developmant KBE = 53,9' E'lExplcratory 7. Unlf or Propen-y Nclme [~JSbaflgraphtc BADAMI L----lservlce 8. Well Number Bl-lla 9. Permit Number 98.34 0, APl Number 50-029-~2829-01 1, Field and Pool Badaml Field / Bc~lc~rnl Oil Fe~l Plugs (measured) Juhk (measured) Casing Length Size Structural Conductor 74' Surface 5026' 9-5/8" Intermediate 10573' 7" Product~cn Liner 2944' 4 1/2" Cemen~d MD TVD 250 s× Arctlset est 11(7 110' 2390 sX PF 'E', N0 sx Class 'G' 5059' 4534' 200 ~ Class 'G' 10606' 8484' 3~ sx CIo~ 'G' 13376' 10475' Perforation depth; measured true vertical Tubing (sEe, grade, and measured depth) Pocke~s and S~SV (Iype and measured depth) d U L 2 4 1998 4 1/2" 12,6# L-80 cf 1032,4'MD HES TNT packer at 1027,4'MD HE$ HXO,_q~V landing ~MD 3, AttacF~nenl's J~-JOescrlptlon summary of oropcsal r~'-lDetailed operations Dr~ram 14, Est'mated dqfe~r~ommenclng operation J 15, Sfas of well cl~slflc~lons ~: I 16, If Drop~al wa~ verbally approved J ~OII ~gas I J ~e~Ce Name of ~prover Date approwdJ Co~lo~gh~erN~m~/~mD~ Pat Collins 564.43~ sketch Lm]suspended Pat Collins .~64-4363 17. Conditions of Approval: Notify Commission so representative may wlfnes~ Plug Integflty BOP Test LoeaUon clearance Me¢*anlcal Integrity Test ~ Subsequent form, required 10L~7 Approved by order of the commission Form 10-403 Rev. 05/15/a8 Robert N. Christeneoe Commls~oner Submit In Triplicate JUL, ~ - UL~ fivi BP Memorandum To: L Purdorn / R. Warner WSA Team Leader Date: July 20, 1998 From' P,Collins AND PE Subject: BADAMI B1-11a Frac Programme B1-1 la was completed with a 4 ~/~" cemented liner on 3/4/98, Frac equipment will be barged from West Dock. Water will be drawn from the lake and heated by a hot oil truck. 2% KCI will be added to the water and mixed on the vac truck. The CTU will be barged out after this and B1-11 a fracs are done if cleanouts are necessary. PTS frac separator will be barged out shortly before startup. 1. Pull the RHC plug. 2. Run a bond log over the 4 Y2" liner. 3. Perforate 13210 - 13250 ft md bkb 40 ft A5 amalgamated 4, Run a Halliburton memory gauge and set in the XN nipple. 5. Pump a 300 bbl data frac. 6. Pull the Halliburton gauge. 7. Redesign and pump the frac, Initial calculations give 198,000 lbs 20/40 proppant. 8. Conduct a CTU cleanout if necessary. 9, Leave the well freeze protected for startup 10. After startup, flow the well back through the PTS flowback separator to clean up proppant. 11. Once the well has been cleaned up, and a welltest obtained, more perforations will be added. These will be on a future programme. The Deviation across the perforated interval is 43°, at an azimuth of 135°, Attachments to this program include: Well completion diagram. Detailed data frac and propped frac program. Design of Slurry Schedule for Tip Screen-out Fracture Technique. Tubing Movement Calculations for Well B1-18. PC CC S.Benoit Wellfile Badaml B1-1 la Frac proceedure Attention: Bob Thayer / Wes Wilder Preliminary Work 1. Pressure test and grease lock Master and Wing Valve. 2, DO NOT EXCEED 8,500 surface pressure. Pre - Frac Treatment 1. Pull RHC plug. 2. Run a bond log over the 4 Y~" liner. 3. Perforate 13210 - 13250 ff md bkb 40' A5 , . , Adjust the WHP to 1200 psi to give 500 psi underbalance at the perfs for the first gun run. Shoot the remainder on balance. Perforation should be with 2 ~A" guns, 6 spf, 60/180° phasing, big hole charges. Run a Halliburton memory gauge and set in the XN nipple. Programme it to cover the data frac. Pressure test annulus to 5,000 psi. Equipment will be brought out by barge from West Dock. Rig up equipment so that BI- 18 and B 1-11 a can be done without moving units. Water will be sucked from the lake by vac truck. KCI is available in 55 lb sacks from Badami drilling and can be sucked onto a partly filled vac truck before being topped up. Keep the vac truck agitated. Water will be heated to 90°F using a hot oiler. Heating can be done before or after KCL is added, as convenient, The water should be pumped into DS tiger tanks via a 3 mm filter. Hydraulic Fracturing Procedure Badami A5 Objective; To create a frac of 250 feet Xlin the Badami A5 sands. Pump injectivity test and datafrac followed by the main fracture treatment. Rig up and stab tree saver, (4" Cameron tree, 4 Ya" L-80 tubing}. The friction pressure is estimated to be 873 psi at 20 bpm, with a surface pressure of 5,009 psi for pad using a fracture gradient of 0.85 psi/foot and a near wellbore friction of 500 psi. Azimuth = 135° Deviation: 45° Pressure test surface lines to 10,000 psi. Expected treating pressure is between 5,000 and 8,000 psi. Observe tdp-out of each pump. After verifying the pump trips, reset the trips to 200 psi above maximum treating pressure, 8,500 psi. JUL, ~) Perform injectivity test: Bullhead 100 bbts of crosslinked gel down to perforation top at 5 bpm. With gel at the perfs, bring the rate up as fast as possible to 20 bpm. Displace injectivity with 30 bbls of 50# linear gel foil°wed by 2% KCI with friction reducer. Over displace all gelled fluid into the perfs by 5 bbls. Shut down and monitor the surface pressure for at least 15 minutes. If the near wellbore friction is > 1,000 psi pump a large fluid slug - 50 bbts and flush. Monitor the decline, if near wellbore friction still high, repeat the procedure. Look at both the value and the rate of change of the near wellbore friction. If, required a proppant slug will then be pumped, see Table 1 below. Once near wellbore friction is ,-- ,500 psi proceed to Datafrac, Note; Have sufficient fluid on site to flush cross linked fluid slugs, 4) Perform 400 bbl Data frac with crosslinked fluid: Pump data frac down to perforations at 5 bpm. With gel at the perfs, bring up rate as quickly as possible to 20 bpm. Over displace data frac by 5 bbls. Displace the data frac with 30 bbl 40 # linear gel followed by 2% KCI water. Stop pumping and monitor the pressure decline. Transmit the data to Anchorage for interpretation, 5) Pull the memory gauge. 6) Discuss closures and leakoff with town. Redesign the TSO. Pump 198,000 lbs fracture treatment at 20 bpm per modified ramp. Freeze protect the tubing with 30 bbls diesel. Table 1 Volumes Volume to Top Perfs Under Flush 200 bbls 5.0 bbls Flush 200 bbls Post- Frac Treatment 1, Determine proppant top with slickline if necessary. 2. If a clean out is necessary, it will be done once B1-18 and 1 la fracs are complete and the frac equipment out of the way. A CTU will be barged from West Dock. Clean out Carbolite per established procedure. An additional programme will be prepared if the operation is necessary. 3. A PTS flowback will be barged to location prior to startup. After startup, flow the well through the separator to clean up proppant. A separate proce'~dure will be sent for this. Well will be produced for 2 to 5 days to clean up of the frac. / \ ATTACHMENT 2 PROPOSED Badami B l- l l FRACTURE TREATMENT $'lurry R~' 'Clean Vol. C]ean Vol. stage Time' Fluid ProPp~t~ T~al -' St~;ge Slurr~ Cum Slurry _STAGE (bpm) (gals) (bbls) (mln) Type Type Proppant (bbls) (bbls) Pad 20 20,000 476 23.80 YFISOD none 0 476,20 476,20 ...... I 20 8,000 I90 9.90 YFIS0D 20140 Carlo 7,998 198.80 . 675 !' 2 20 .1,630 39 2,10 YFISOD 20140 Carb 3,2.59 42.20 717 :. 3 20 2,410 '5'7 ' 3.20 Y~=~'SOD 20/40 Carb 7,228 64.90 782 4 - 20 3.040 72 4.30" YF150D 20/40 Cart) 12,157 85.10 867 $ 20 3,540 84 5.10 YFISOD 20/40 Carb · 17,696 102.80 ' 970 6 20 3,910 93 5.90 YF160D 20/40 carb 23,455 117',60 10Bl~ 7 20 4, t80 100 6,S0 YF160D' 20140 Garb 29,254 130.10 1218... B 20 4,350 104 7,00 YF150D 20140 Carb 34,800 139.90 1358 9 " ~ 4,460 106 7.40 YFI$0D 20/40 C~rb . 40,140 148.10 15Q6 -10 .-20 _. 2,210_. 53 3.80 YFI~50D 2O~40 CArb 22,100 75:?0' 151~! Flush 20 8,505 203 10,10 Se.~ Water rlone , 0 203.00: 171[I4 To=Is ..... 57,730.i'" ~375 79,~10 YFf 50D DELAYED BORATE FLUID SYSTEM SHOULD CONTAIN F. HE FOLI:OWt~iG ~DDIT_TVE$: Crosslinker L-10 BREAKER J-218 aqd J-~75 Bactericide M-~75: ' . Activator j-899 Surfactant F,75N. -' - -, ** - - On 50# gel flush stage, simply cut the L-10 and J-899. Breaker schedule J-475 J-218 Fluid Loss Silica Flour Adomite Regain Injectivlty, Oatafrac & Pad 1.0 ppt 0 ppt 15 ppt 40 ppt Stages 2 to 6 (ramp) 2 - 5 ppt 0 ppt 0 0 Stage 7 & 8 6 ppt 0.5 ppt 0 O Tubing Movement Calculations for Well B1-1 la Anchorec LB0 Tubing Piston & Plug Effect Ballooning Effect Pressure Across Pqcke~ - L_pr = -87,60 inches -L_bal = 16.69 inch~ -P = -5207 psia (up) -F_pr = -76747 lbs -F_bal = -14626 lbs _ Pressure Buckling Temperature Effect F_tp = -90751 lbs (up) 'L_hb = 0.00 inches 'L_fmp = -32.68 inch~ F_pc = -185728 lbs (up) 2 Sfiings VeT 3.2d ITotal Length Change 0 inches 0.0 feet tubing -> packer fore packer-> casing for( n = 0 feet 'F_tmp = 28631 lbs -Minimum Design .Factor: Input, all strin(;~Ji~o to bottom far Inslructions) Oplh'ons: ("X" to select) 1.53 VME String 90 Final Surface Temp, (°F) ~! Ignore Ptpe Tolerance for ~(tel~ci~4:~k fo use APt folerance)l 8500 Final Applied Tubing Pressure (p x Anchored Tubing (Leave Blank for Floating/Pinned tubing)l , ~ Finat Applied Annular Premure (psi) 13Cr ~ank for LB0. Use Tubing optlan to define o~er tubing)l ~ Ini~l Surface Temperature (~ [~ Tubin~ N~ I(Npe) ~ 3E+71 B~ pJ O.30J 5~ InlfiaJ Applied fbg. Pressure (~i)l ~ Sour ~Nice (Leave Blank for ~eet SeNice)~ 0 fnilial ~plied Ann, Pressure (psi~ Mechanical set Comple~on (Leave Blank for Hydro~ 3,875 Packerseal ~re diamefe~(in) /~ Plug inTailpipe P below plug~ l~i~ ~kr~tl X I 0 SJackoff(l~) -Compre~.. +Tension Pinn~d at ~ I lbs ]ve blank for Free Mov~ 31 2 IStrings 'Deign Factom ~Top and Boffom of Each Siring 2~I 10274J ]MD bottom (fi) Ancho~edTubing Floa~n~ tubing 2~I ~861 I~bo.o~(,) 'SJT~,, ~,74 T~., 2.05 T~,, 3.~ T~ 5,77 3.958J 3.958j rTbgLD.(i,) TjBurst 2,41 Bumt 2.07 Burst 2.41 Burst 2.07 4,5J 4.5J jTbgO,D,(in) ]Calla[ N/A Collap N/A Colla¢ N/A Colla¢ NIA 8~J 8~J JTbg~eld (psi) llVME 1.53 VME 1.~ VME 2.37 VME 2.22 12,61 12.6J JTbgWeight(Ibs/ff) ~SJTens 2.05 Tens 4.59 Tens 5.77 Com~ 10,29 6. J~J 6,~4~ I~,'~,.~.~,.)I rl~,,~ 2.0~Burst 1.62 Bu~t 2,07 Bu~t 1.62 ~2.8j T2.~J JFina~bs/ga,~bg J JColla~ N/A Coilap N/A Colla[ N/A Colla[ N/A 7,2J 8.7J ]Initial ~bs/gal~g J 2JVME 1.~ VME !,73 VME 2,22 VME 1,~ 7,=I ~'~1 ~F~.~lg., ~.n I SrT~., ~,~ Co~ Co~ 7,2J 8,7J ]Initial lbs/gar ann J T ]Burst Bu~t Burst Burst 95j 110] ]Final botTemp CF) JColla~ Collap Collo~ Collap ~J l~J Jlni~al hot femp CF 3JVME VME VME 0j 0J J-P ~rio~on m~itu, J -Top ~m' Top 0J 0J ]Dogleg ¢/!~ ~) * Denotes Design FaCtors Below B~;~ Sugge~ed Minimum BPX Suggested design minimums iLoad capacJ~'~ension 1.~ Load c~ci~Cal~apse '"' 1.10 VME(sweel seMce) 1;2~ Load capaciN Compre: 1,~ Load capaci~ Bu~t !,30 VME (sour ~ice) 1, Nole: Tubing m~gement calcul~i'ons a~ from the BP C~pletion Design Manual Volume 11 1,) For ~chored tubing, weak link b fop af tubing ar Anchor ~al: keep Te~Jon and VME factars abave minimu 2,) ~r Floaffng seal assembly over stip~E~ep Total n~Ne length ~nge << SIIp~ick Length 3.) For Pinned seal ~mbly over sli~tick pins will shear and ~blng ~11 ~_~ If> ~n ~enCh ; ' Ul:).rlYt t'~u, JU ~- r. B1 11A Ill I I Il · I II Kelly bushing lo wellhead (fi) Wellhead I0 sea 35.3 18.6 Conduclor H40 30.000 t 9.124 gl 110,O 56.1 " L-80 NSCT Pm~ion Tubing 4,500 3,958 ~2.6 HES "X" Safe~y V~ve Landing Nipple 4,~0 3.813 ~06.8 2142,6 ~L-80 Surface C~ing 9.6~ 8_8~ 40 5059,0 ~0.0 H~S "~ Pe~anent P~ck~ 5.875 3,958 23-29 1 ~74,3 8186.3 HES "X" Landhg Nipple, 9CR 4.500 3.813 10~912 alge,5 HES "XN" Landing Nipple, 9CR 4,500 3.725 10311,7 8213.2 ~rellne Enl~ Gu~e 5.250 3,958 10~3.9 8222,1 P x 4 112" Liner Hang~/Packer 10430.0 8299.6 In~ermedi,le Casing 7.000 6.184 2g 10605.0 PBTD 1~88,0 1~.0 Produdion Liner 4 .~00 3.gS8 12,6 13375.0 10421 ,, Dale Rev, by Commsn~s,,, ~/or~? B.Tumbull Inilial design 24~o~/~7 B.Tumbull I;{omoved GL mandrel and X-nipple 17/oe/e~.B.Tumbull As built c~mensions added Memorandum To: S.Benoit From: Subject: P.Collins AND PE BADAMI B1-1 la Post Startup Pe...rf. oration Programme Date: July 22, 1998 B1-1 la has a frac programme awaiting completion, The A5 amalgamated sands will be fracced. After startup, the well will be flowed through a PTS separator to clean up. Once a welltest has been obtained, more perfs will be added as detailed below. 1. Run a TD tag to determine proppant fill. 2. Perforate 13062- 13210 ft md bkb 148' A5 interbedded 3. When the WHT has stabilised, obtain a welltest. 4. Perforate 12680 - 12750 ft md bkb 70' J2 lobe 5. When the WHT has stabilised, obtain a welltest, 6. Perforate 12610 - 12670 fl md bkb 60' J1 lobe Perforation should be with 2 -%" guns, 6 spf, 60/180° phasing, Predator deep penetrating charges. Perforation should be underbalanced with the well flowing at a Iow rate, choked back as necessary to prevent tool movement, The Deviation across the perforated interval is 43°. PBTD is at 13288 ft MD bkb. Attachments to this program include: · Well completion diagram · Minilog PC cc L Koenn, Atlas Wellfile JUL 2 4 1998 Alaska 0il & Gas Cons. Commis~i~ Kelly bushing lo wellhead (It) Wellhead to .I. 3~,3 18.6 i, 6d Oonductor H4O L-~O NSCT Producllon Tubing HES '~" Safety Va~'e Landing Nipple L.80 Surface casing 56,1 2142.6 4~,80.0 "TNT'' Permanen! Packer HES "X" Landing Nipple, 9CR HES "XN~ Landing Nipple, 9CR Wifeline Entry Guide 8186.3 8198.5 8213.2 8222.1 7" x 4 1/2" Liner Hanger/Packer Intmmedisle Casing 8299,6 84~9,8 .al,,. PBTD Production Liner 10356.0 10421,0 Rev by Commen[s B.Turnbull B.Tumbull B.Tumbull Iniliel design Remeved GL mandrel and X-nipple As buill dimensions added .... STATE OF ALASKA '- ..... ~ E C E IV E D ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOGUL 1998 1. Status of Well Classification ¢fl~l~41S cons. E~Oil E~Gas []Suspended []Abandoned []Service Pre-Produced Injector Anchorage 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-34 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22829-01 4. Location of well at surface ~ ~ ~ 9. Unit or Lease Name 3854' NSL, 156' WEL, SEC. 8, TgN, R20E, UM j~'-'-';r~O~:r."-:_~ ~ :~ ''::~ ::: .... ~ :~.~ ~m~'"'"~--"~""' Badami Unit At top of productive interval i~-~'~z~i~._.r' :, ~-':~i~i ' 10. Well Number N/A , . ~ B1-1 lA i 11 Field and Pool At total depth ._~.,~_.].]_~ ! . 5034' NSL, 2742' WEL, SEC. 5, T9N, R20E, UM '-: ' ................ Badami 5. Elevation in feet (indicate KB, DF, etc.) J C. Lease Designation and Serial No. KBE = 53.9'I ADL 367011 12. Date Spudded2/21/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if Offsh°re 116' N°' °f C°mpletiOns2/27/98 N/A N/A MSLI One 17. Total Depth (MD+TVD) J18. Plug Back Depth (MD+TVD)I'i9. Directional S'~rvey J20. Depth where SSSV set j21. Thickness of Permafrost 13375 10475 FTI 13288 10410 FTI [~Yes I~NoI (nipple) 2207 MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR/RES LWD 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 36' 110' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 5059' 12-1/4" 2390 sx PF 'E', 340 sx Class 'G' 7" 29# USS-95 33' 10606' 8-1/2" 200 sx Class 'G' 4-1/2" 12.6# L-80 10431' 13375' 6" 350 sx Class 'G' 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) None 4-1/2", 12.6#, L-80 10324' 10274' MD TVD MD TVD 26. ACID, 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.) ~ N/AI Facility not on line yet Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE leAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL iGAS-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. 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. .. Bottom Badami Sands A5 13255' 10385' Badami Sands CM3 11845' 9396' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Mike E. Miller ~, .. Title Badami Drilling Team Leader B1-1 lA 98-34 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 Performance Enquiry Report Operator BP Exploration Date 01:23, 23 Jun 98 Page The analysis is from - 14:00, 22 Jan 98 - to - 03:30, 30 Jan 98 Programs in Result Table: B 1-11 Well TyDe BI-11 Event BI-ll Event Time From Time TO Duration Description E.M.W.(equivalent mud weight) 14:00, 22 Jan 98 14:00, 22 Jan 98 0 hr 0 min Obtained leak off 12.0 03:30, 30 Jan 98 03:30, 30 Jan 98 0 hr 0 min Obtained required level of integrity 15.5 Hole Size MDR 8-1/2 6 Facility Badami CPF Progress Report Well BI-llA Page 7 Rig Nabors 28E Date 22 July 98 Date/Time 15 Feb 98 16 Feb 98 17 Feb 98 18 Feb 98 19 Feb 98 20 Feb 98 21 Feb 98 06:30-14:00 14:00-15:00 15:00-22:00 22:00-22:30 22:30-03:00 3:00-06:00 (:00-09:00 09 10-12:00 12:{ 14:01 16:00- ):45 02:45-04 14:00-16:30 16:30-17:00 17:00-17:45 06:00-09:00 09:00-15:00 15:00-17:00 17:00-02:30 02:30-03:00 03:00-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-12:00 12:00-15:30 15:30-00:30 00:30-02:30 02:30-06:00 06:00-09:45 09:45-1 11 12:30-17: 17:30-1:30 18:30- )1:00 01:0 .02:00 02:, )-06:00 )0-06:15 0 15-06:30 1-07:00 )7:00-09:30 09:30-10:00 10:00-13:30 13:30-14:00 14:00-16:00 Duration 7-1/2 hr lhr 7hr 1/2 hr 4-1/2 hr 3 hr 3 hr 3hr 2 hr 2hr 4-3/4 hr 6hr 1-3/4 hr 1-1/2 hr 8hr 2-1/2 hr 1/2 hr 3/4 hr 2 9-1 1/2 1/2 1/2 1 1 hr hr 3-1/2 hr 9hr 2hr 3-1/2 hr 3-3/4 hr 1-3/4 hr lhr 4-1/2 hr 1/2 hr lhr 5-1/2 hr lhr lhr 4 hr 1/4 hr 1/4 hr 1/2 hr 2-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 2hr 16:00-06:00 06:00-14:00 14 hr 8hr Activity Pulled Made R.I.H. in stands to 95.0 ft BHA no. 15 12455.0 ft at 12480.0 ft stuck pipe at 12480.0 ft stuck pipe at 12480.0 ft stuck pipe at 12480.0 ft stuck pipe at 12480.0 ft at 12480.0 ft at 12480.0 ft Conducted electric cable operations Pulled Drillpipe in stands to 863.0 ft Pulled BI-IA Ran Tubing to 506.0 ft (2-7/8in OD) Ran Tubing to 12369.0 ft (2-7/8in OD) Circulated at 12396.0 ft Mixed and pumped slurry - 30.000 bbl Displaced slurry - 110.000 bbl Laid down 1263.0 ft of Tubing Tested BOP stack Made up BHA no. 16 Singled in drill pipe to 8731.0 ft R.I.H. to 10591.0 ft Circulated at 10591.0 ft R.I.H. to 11401.0 ft Took MWD survey at 11401.0 ft R.I.H. to 11460.0 ft R.I.H. to 11438.0 ft (cont...) Drilled cement to 11560.0 ft Drilled to 11560.0 ft Drilled cement to 11689.0 ft Drilled to 11702.0 ft Reamed to 11702.0 ft Drilled to 11708.0 ft to 11713.0 ft holled 11793.0 ft to lated at 11793.0 ft out of hole to 200.0 ft BHA no. 17 70.0 ft survey at 11742.0 ft hole to 10620.0 ft ole to 1100.0 le to 200.0 ft (cont...) Pulled BHA ~ Made up BHA hQ. 18 R.I.H. to 2000.0 ~ Held safety meetin~ ~.I: .H. to~ 9000.0 .ft Held safety meeting R.I.H. to !1766.0fl k ~~ Drilled to 11809.0 ft Drilled to 11845.0 ft (cont...) Progress Report Facility Badami CPF Well BI-llA Rig Nabors 28E Page 8 Date 22 July 98 Date/Time 14:00-14:30 14:30-18:30 18:30-19:00 19:00-19:30 19:30-20:00 20:00-21:00 21:00-21:30 21:30-02:00 22 Feb 98 02:00-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:00 23 Feb 98 06:00-12:30 12:30-14:00 14:00-18:30 18:30-19:30 19:30-20:30 20:30-00:00 24 Feb 98 00:00-02:30 02:30-06:00 06:00-06:15 06:15-06:30 06:30-09:00 09:00-13:00 13:00-14:00 14:00-14:30 14:30-15:00 15:00-18:00 18:00-22:00 22:00-06:00 25 Feb 98 06:00-06:00 26 Feb 98 06:00-13:30 13:30-14:00 14:00-14:15 14:15-14:30 14:30-06:00 27 Feb 98 06:00-10:30 10:30-13:30 13:30-14:30 14:30-15:30 15:30-18:30 18:30-19:00 19:00-01:00 28 Feb 98 01:00-04:30 04:30-04:45 04:45-05:30 05:30-06:00 06:00-10:00 10:00-17:00 17:00-17:30 17:30-22:00 22:00-23:00 23:00-00:00 Duration 1/2 hr 4hr 1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 4-1/2 hr 1 hr 1-1/2 hr lhr 1/2 hr 24 hr 6-1/2 hr 1-1/2 hr 4-1/2 hr lhr lhr 3-1/2 hr 2-1/2 hr 3-1/2 hr 1/4 hr 1/4hr 2-1/2 hr 4hr lhr 1/2 hr 1/2 hr 3hr 4hr 8hr 24 hr 7-1/2 hr 1/2 hr 1/4 hr 1/4 hr 15-1/2 hr 4-1/2 hr 3hr lhr lhr 3hr 1/2hr 6hr 3-1/2 hr 1/4 hr 3/4 hr 1/2 hr 4hr 7hr 1/2 hr 4-1/2 hr lhr lhr Activity Flow check Pulled out of hole to 1100.0 ft Pulled BHA Made up BHA no. 19 Removed Bore protector R.I.H. to 11745.0 ft Rig waited: Assessed situation R.I.H. to 10545.0 ft Serviced Block line R.I.H. to 11745.0 ft Washed to 11845.0 ft Drilled to 11850.0 ft Drilled to 12129.0 fi (cont...) Drilled to 12129.0 fi (cont...) Circulated at 12223.0 fi Pulled out of hole to 200.0 fi Pulled BHA Removed Wear bushing Tested BOP stack Rig waited: Equipment Tested Well control Retrieved BOP test plug assembly Installed B ore protector Made up BHA no. 20 Tested Kelly cocks Tested MWD - Via string R.I.H. to 3990.0 ft Tested MWD - Via string R.I.H. to 11780.0 ft R.I.H. to 12223.0 ft Drilled to 12341.0 ft Drilled to 12826.0 fi (cont...) Drilled to 12975.0 ft (cont...) Circulated at 12975.0 ft Pulled out of hole to 12170.0 ft R.I.H. to 12795.0 ft Drilled to 13280.0 ft Drilled to 13375.0 ft (cont...) Circulated at 13375.0 ft Pulled out of hole to 10605.0 ft R.I.H. to 13375.0 ft Circulated at 13375.0 ft Circulated at 13375.0 ft Pulled out of hole to 168.0 ft Pulled BHA Held safety meeting Rigged up Handling equipment Ran Liner to 200.0 ft (4-1/2in OD) Ran Liner to 2914.0 ft (4-1/2in OD) Ran Tubing to 2826.0 ft (2~7/8in OD) Circulated at 3040.0 ft Ran Liner on landing string to 10500.0 ft Circulated at 10500.0 ft Cleared Cement head Progress Report Facility Badami CPF Well B 1-11A Rig Nabors 28E Page 9 Date 22 July 98 Date/Time 01 Mar 98 02 Mar 98 03 Mar 98 04 Mar 98 00:00-00:30 00:30-03:30 03:30-06:00 06:00-08:30 08:30-10:30 10:30-11:00 11:00-12:30 12:30-13:00 13:00-17:30 17:30-19:30 19:30-04:00 04:00-06:00 06:00-07:30 07:30-08:30 08:30-09:30 09:30-11:00 11:00-11:30 11:30-12:30 12:30-13:00 13:00-14:30 14:30-22:30 22:30-23:00 23:00-06:00 06:00-08:30 08:30-09:30 09:30-10:00 10:00-11:00 11:00-15:30 15:30-18:00 18:00-20:30 20:30-21:30 21:30-01:00 01:00-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-06:45 06:45-07:30 07:30-08:30 08:30-12:00 12:00-15:00 Duration 1/2 hr 3hr 2-1/2 hr 2-1/2 hr 2hr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 2hr 8-1/2 hr 2 hr 1-1/2 hr lhr lhr 1-1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr 8hr 1/2 hr 7hr 2-1/2 hr lhr 1/2 hr 1 hr 4-1/2 hr 2-1/2 hr 2-1/2 hr lhr 3-1/2 hr 3hr 1/2 hr lhr 1/2 hr 3/4 hr 3/4 hr lhr 3-1/2 hr 3hr Activity Held safety meeting Ran Liner on landing string to 13375.0 ft Circulated at 13375.0 ft Circulated at 13375.0 ft (cont...) Mixed and pumped slurry - 72.000 bbl Retrieved downhole equipment - Liner hanger Circulated at 13274.0 ft Tested Liner Circulated at 13274.0 ft Tested Liner - Via annulus Laid down 10400.0 ft of 4in OD drill pipe Laid down Tubing of 2826.0 ft Laid down 2826.0 ft of Tubing (cont...) Ran Drillpipe in stands to 1786.0 ft Serviced Block line Laid down 1786.0 ft of 4in OD drill pipe Retrieved Bore protector Rigged down Drillstring handling equipment Held safety meeting Conducted electric cable operations Conducted electric cable operations Retrieved B ore protector Ran Tubing to 4-1/2in (7200.0 ft OD) Ran Tubing to 10293.0 ft (4-1/2in OD) (cont...) Tested Tubing hanger Rigged down Tubing handling equipment Rigged down BOP stack Serviced Top ram Removed BOP stack Rigged up Wellhead integral components Retrieved Hanger plug Circulated at 1.0 ft Circulated at 10323.0 ft Serviced Permanent packer Set packer at 10274.0 ft with 5000.0 psi Tested Tubular strings - Via annulus Tested Tubing Tested Tubing Installed Hanger plug Cleared Shaker discharge line Rigged down Well control SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 BP EXPLORATION BADAMI / Bi-ll~ 500292282900 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/11/98 DATE OF SURVEY: 022798 MWD SURVEY JOB NUMBER: AKVC80075 KELLY BUSHING ELEV. = 53.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11725.74 9307.23 9253.33 42 47 N 12.80 W .00 5611.58N 1814.50W 5869.38 11780.54 9347.54 9293.64 42 30 N 13.10 W .66 5647.76N 1822.82W 5905.88 11812.78 9371.92 9318.02 39 12 N 15.50 W 11.33 5668.20N 1828.01W 5926.69 11844.48 9396.68 9342.78 38 5 N 18.40 W 6.68 5687.13N 1833.78W 5946.35 11875.74 9421.26 9367.36 38 12 N 22.70 W 8.50 5705.20N 1840.55W 5965.62 11907.54 9446.08 9392.18 39 12 N 26.50 W 8.11 5723.27N 1848.83W 5985.49 11939.42 9470.63 9416.73 40 5 N 29.70 W 7.00 5741.20N 1858.41W 6005.76 11970.73 9494.46 9440.56 40 47 N 33.40 W 7.98 5758.50N 1869.04W 6025.87 12002.37 9518.21 9464.31 41 54 N 37.90 W 10.02 5775.47N 1881.23W 6046.29 12033.91 9541.51 9487.61 42 54 N 41.40 W 8.13 5791.84N 1894.80W 6066.71 12065.59 9564.30 9510.40 45 5 N 43.90 W 8.85 5808.01N 1909.71W 6087.50 12097.05 9586.03 9532.13 47 30 N 45.10 W 8.11 5824.23N 1925.65W 6108.73 12128.59 9607.17 9553.27 48 17 N 46.60 W 4.35 5840.53N 1942.44W 6130.37 12159.80 9627.89 9573.99 48 30 N 46.90 W .96 5856.52N 1959.44W 6151.82 12251.32 9688.42 9634.51 48 42 N 46.90 W .22 5903.42N 2009.57W 6214.84 12346.38 9751.22 9697.32 48 35 N 46.80 W .13 5952.23N 2061.63W 6280.37 12440.09 9813.43 9759.53 48 12 N 45.80 W .91 6000.64N 2112.29W 6344.98 12533.10 9875.79 9821.89 47 35 N 45.70 W .65 6048.79N 2161.72W 6408.87 12627.12 9939.61 9885.71 46 54 N 46.20 W .84 6096.80N 2211.34W 6472.69 12722.26 10004.74 9950.84 46 42 N 45.90 W .31 6144.93N 2261.27W 6536.75 12816.32 10069.72 10015.82 45 54 N 46.30 W .90 6192.08N 2310.27W 6599.55 12911.38 10136.17 10082.27 45 24 N 45.60 W .74 6239.34N 2359.13W 6662.38 13004.32 10202.06 10148.16 44 17 N 45.60 W 1.18 6285.20N 2405.96W 6723.12 13098.78 10270.23 10216.33 43 17 N 45.50 W 1.06 6330.98N 2452.63W 6783.73 13193.55 10339.71 10285.81 42 24 N 46.20 W 1.07 6375.88N 2498.87W 6843.35 13288.26 10409.98 10356.08 41 47 N 46.40 W .65 6419.74N 2544.77W 6901.90 13310.43 10426.53 10372.63 41 35 N 46.20 W 1.09 6429.93N 2555.43W 6915.50 13375.00 10474.82 10420.92 41 35 N 46.20 W .03 6459.60N 2586.38W 6955.05 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6958.15 FEET AT NORTH 21 DEG. 49 MIN. WEST AT MD = 13375 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 336.47 DEG. TIE-IN SURVEY AT 11,725.74' MD WINDOW POINT AT 11,793.00' MD PROJECTED SURVEY AT 13, 375.00' MD ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION BADAMI / Bi-ii 500292282900 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/11/98 DATE OF SURVEY: 022798 JOB NUMBER: AKVC80075 KELLY BUSHING ELEV. = 53.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11725.74 9307.23 9253.33 12725.74 10007.12 9953.22 13375.00 10474.82 10420.92 5611.58 N 1814.50 W 2418.51 6146.69 N 2263.09 W 2718.62 300.11 6459.60 N 2586.38 W 2900.18 181.56 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION BADAMI / BI-ii 500292282900 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/11/98 DATE OF SURVEY: 022798 JOB NUMBER: AKVC80075 KELLY BUSHING ELEV. = 53.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL . DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11725.74 9307.23 9253.33 11789.07 9353.90 9300.00 11917.64 9453.90 9400.00 12051.04 9553.90 9500.00 5611.58 N 1814.50 W 5653.28 N 1824.16 W 5728.97 N 1851.73 W 5800.58 N 1902.75 W 2418.51 2435.17 16.66 2463.74 28.57 2497.14 33.40 12199.05 9653.90 9600.00 12350.44 9753.90 9700.00 12500.64 9853.90 9800.00 12648.04 9953.90 9900.00 12793.58 10053.90 10000.00 5876.60 N 1980.91 W 5954.31 N 2063.85 W 6032.05 N 2144.56 W 6107.37 N 2222.37 W 6180.80 N 2298.47 W 2545.15 48.01 2596.54 51.39 2646.74 50.20 2694.14 47.40 2739.68 45.55 12936.63 10153.90 10100.00 13076.34 10253.90 10200.00 13212.77 10353.90 10300.00 13347.02 10453.90 10400.00 13375.00 10474.82 10420.92 6251.92 N 2371.97 W 6320.20 N 2441.65 W 6384.85 N 2508.22 W 6446.75 N 2572.97 W 6459.60 N 2586.38 W 2782.73 43.05 2822.44 39.71 2858.87 36.43 2893.12 34.26 2900.18 7.06 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS BP EXPLORATION, Alaska Date: 05-04-98 Trans# 89075 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) 564-4944. Sw Name Rec Type Log Type Meas Depth Meas Depth Comments Top Base B1-18 OH BOREHOLE 8,828. 10,726. 4-ARM CALIPER GAMMA RAY LOG BOREHOLE PROFILE PROFILE B1-18 OH FMT 9,119. 10,420. FORMATION MULTI-TESTER GAMMA RAY LOG B1-18 OH MWD DGPJEWR 6,923. 10,726. MWD ROP NGP DGR EWR4 B1-18 OH MWD DGR/EWR 6,800. 10,423. TVD -MWD NGP DGR EWR4 B1-11 OH MWD GR 5,075. 13,350. MWD ROP NGP B1-11 OH MWD GR 4,545. 10,580. TVD - MWD NGP B1-11A .OH MWD DGR/EWR 5,075. 13,375. MWD ROP NGP DGR EWR4 B1-1 lA OH MWD DGR/EWR 4,545. 10,475. TVD -MWD NGP DGR EWR4 B1-18 DISK MWD DGR/EWR 6,856. 10,673. NWD MPT GR EWR4 ROP ASCII FORMAT Please sign and return one copy of this transmittal to: Nadene Reichert Petrotechnical Data Center LOG DATA AOGCC- 1 disk/1 blueline/1 sepia PETROFINA- I disk/1 blueline/1 sepia DNR- I disk/1 blueline BP -- I blueline BP ---1 correlation log blueline Howard Oakland Mike Magalski Tim Rhyherd Jill Kanosh Ken Lemley Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 04-13-98 Trans# 89022 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) 564-4944. Sw Name Log Type Rec Date Meas Depth Meas Depth Comments Top Base B1-01 CCL 26-Mar-98 7,986. 8,392.1GAMMA RAY LOG/CASING COLLAR LOG Bl-11A MWD EWR 27-Feb-98 5,007. 13,327. MWD GR EWR4 ROP ASCII FORMAT B1-11 MWD GR 09-Feb-98 5,007. 13,284. I MWD GRC ROP ASCII FORMAT Please sign and return one copy of this transmittal to: Nadene Reichert Petrotechnical Data Center LOG DATA AOGCC- 1 disk/1 blueline/1 sepia PETROFINA- 1 disldl blueline/1 sepia DNR - 1 disk/1 blueline BP -- I blueline Howard Oakland Mike Magalski cc:Jill Kanosh Tim Rhyherd Alistair Bent Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 04-07-98 Trans# 89008 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) 564-4944. ~.~._ C)~ Sw Name Log Type Rec Date Meas Depth Top Meas Depth Base Comments B1-1 lA SBL 20-Mar-98 10,422. 13,256. SEGMENTED BOND TOOL, - GAMMA RAY LOG - CASING COLLAR LOCATOR B1-1 lA GR 21-Mar-98 10,535. 13,255. MULTIPOLE ARRAY ACOUSTILOG - GAMMA RAY LOG Please sign and return one copy of this transmittal to: Nadene Reichert Petrotechnical Data Center LOG DATA AOGCC- 1 disk/1 blueline/1 sepia PETROFINA- 1 disk/1 blueline/1 sepia DNR- 1 disk/1 blueline BP - - 1 blueline Howard Oakland Mike Magalski cc:Jill Kanosh Tim Rhyherd Alistair Bent Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 TONY KNOWLE$, GOVERNOR ALASi~& OIL ~ GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 25. 1998 Steve Shultz Engineering Supcrx'isor BP Exploration t. Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 ac~ Prudhoc Bay Unit B 1- I 1A BP Exploration (Alaska) Inc. Permit No. 98-34 Sur. Loc: 3854'NSL. 156'WEL. Sec. 08. T09N. R20E. UM Btmhole Loc: 501 I'NSL. 2938'WEL. Sec. 05. T09N. R20E. UM Dear Mr. Shultz: Enclosed is thc approved application for permit to rcdrill thc above referenced x~'ell. Thc permit to rcdrill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximatcly 24 hours) of the BOPE tcst performed before drilling below the surface casing shoe must bc given so that a representative of thc Commission ma,,' witness the test. Notice may be givcn bx' contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. Chairn~an ~ BY ORDER OF THE COMMISSION dlf/Enclosurc cc~ Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. ,' STATE OF ALASKA AL~ .,jKA OIL AND GAS CONSERVATIO~COMMISSION ~ PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 53.9' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 367011 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3854' NSL, 156' WEL, SEC. 8, T9N, R20E, UM Badami Unit At top of productive interval 8. Well Number /~., Number 2S100302630-277 4945' NSL, 2850' WEL, SEC. 5, T9N, R20E, UM B1-11 At total depth 9. Approximate spud date Amount $200,000.00 5011' NSL, 2938' WEL, SEC. 5, T9N, R20E, UM 11/26/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 367006, 269'I B1-01,96.37' at 1798' MD 2533 13520' MD / 10654' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e) (2)} KickOff Depth 11700' MD Maximum HoleAn,qle 43-83° Maximum surface 4400 psig, At total depth ('rVD) 10094'/6326psig 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) 6" 4-1/2" 12.6# L-80 NSCT 3269' 10251' 8295' 13520' 10654' 368 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary i'~ [L~.* f ~-" Total depth: measured 13550 feet Plugs (measured) true vertical 10579 feet Effective depth: measured 12480 feet Junk (measured) Stuck BHA at 1,_~,.,,, true vertical 9879 feet Casing Length Size Cemented MD TVD Structural Conductor 75' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 5025' 9-5/8" 2325 sx PF 'E', 340 sx Class 'G' 5059' 4534' Intermediate 10573' 7" 200 sx Class 'G' 10606' 8484' Production Liner ORIGINAL Perforation depth: measured N/A As per instructions from Blair Wondzell: Formation characteristics, rig and programs for the casing, mud, and logging all remain the same. true vertical The only change is the directional, which is attached herewith. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diver[er 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 Campoamor, 564-5122 21. I hereby certify that thong is t~/u~ ~ to the best of my knowledge Signed Steve Shultz ~ ~ Title Engineering Supervisor Date , ~e? ~¢~,,'~(~ %~ ~p.~ Commission Use Only Permit Number I APl Number Approval Date I See cover letter ~:~"',-~ ~//I 50-029-22829 - o / 11/19/97I for other requirements Conditions of Approval: Samples Required []Yes [] No Mud Log Required []Yes J~No Hydrogen Sulfide Measures []Yes ~ No Directional Survey Required []Yes [] No Required Working Pressure for BOPE []2M; []3M; ~5M; []10M; []15M Other: 0fi[~'RS-' S'6Jrl(~0 d~j byorderof Approved By ~SVi~ W. J0hr~st0r~ Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Tr plicate DI~;L.i.I N G- I DrillQuest'l -2S50 -2250 I I ~11.46tt MD, 10531 &(X)O"/100fl: 11700.OOfl MD, g~88.37R TVD LOIGO ooo BI-I l ~ Tatgcl 1O429.90 TVD 6371.40 lq)2711.81 W l~oo .oo I.OO DIr, Sail 0 47.316' - 12060.11fi MD, 9547.6;3ft 'I'VD End Oif, Sail 0 47.316°: 12060.1 lfl MD, 9647.631t '['VD s,as~ Scele: L23Q D. OO ;~O. OD L2g00.O3 6150 KOP: Start Olr 0 8.000°ll00ft: 11700.00fi MD, 9288.371t TVD I I ' -2250 495O 3100. Gl) FOR PERMITTING ONLY I 6450 Vertical Section B 1-11 ~'T T~get 1O429.9O TVD 6371.40 N, 27 ! 1.81 W : 13511.~b-'tt MD. 10531.59~TVD Sperry-Sun Drilling Services Proposal Report for B1-11 - B1-11 WplO Badami FOR PERNtlTTING ONLY Depth In~. Azhn. D~h Oe~h (ft) (it) (ft) Local Coorm~ Glob~ ~ ~ veru~ (n) (fi) (n) ~ ('flooft) 11700.00 42.989 347.473 9234.47 928~,37 11800.00 42.688 335.704 9307.,92 9361.82 11900.00 43,588 324.067 9381.01 9434.91 12000.00 45.615 313.035 9452.31 9506.21 12060.11 47.316 306~29 9493.73 9547.63 12100J)0 47316 3(:16J629 9620.76 9574.66 12200,00 47.316 306.829 9588.58 0642.48 12300.00 47.316 306.829 9656.37 9710.27 12400.00 47.316 306.829 g'/24.17 9778.07 12500.00 47.316 306.629 9791,96 9~45.86 12600.00 47.316 306.029 9859.76 9913.66 1270().00 47.316 306.829 9927.55 9981.45 12800.00 47.316 306.B29 9995.35 10049.25 12900.00 47.316 306.829 104)63.1.5 10117.05 13000.04:} 47.316 306.629 10130.94 10184.64 13100.00 47.316 306.829 1019~.74 10252.64 13200.00 47.316 306.829 10266.53 t0320.~ 13300.00 47.316 306.829 10334.33 I ~23 133~1.46; 47.316 306.829 10376.00 10429.90 13400.00 47.3~6 306.829 10402.13 10456.03 13500.00 47.316 306,829 10469.92 10523.82 13511.46 47.316 30~.829 10477.69 10531.59 5594.49 N 1810.66 W 5912051.01 N 362146.04 E 5879.85 56~8.77 N 1632.O4 W 5912115.67 N 3~2125.82 E 8.000 5947.59 5717.68 N 1866.27 W 5912175.18 N 362092.66 E 8.(XX) 6014.33 5770.06 N 1912.70 W 5912228~ N 362047.18 E 8.0(X) 6078.77 5797.96 N 1946.10 W 5912256.60 N 362~14.29 E 8,(X)O 6115.87 5815.56 N 1969.57 W 5912:274.90 N 361901.13 E 0.1XX) 6140.00 5859.62 N 2028.41 W 5912:320.02 N 361933.09 E O.0(X) ~t204).51 5903.68 N 2087.25 W 5912:365.13 Fi 361875.06 E 0.0(X) 6261.01 5947.75 N 2146.09 W 5912410.24 N 361817.02 E 0.000 6321.51 5991.81 N 2204.93 W 5912455.36 N 361758.98 E 0.(XX) 6382.01 6035.8'7 N 2263.77 W 5912500.47 N 361700.94 E 0.000 6442.51 6079.94 N 2322.61 W 5912:545.59 N 361642.90 E 0.0(30 6503.02 6124.00 N 2381.45 W 5912590.70 N 361584.86 E 0.000 6563.,62 616~.06 N 2440.29 W 59126,35.81 N 361526.83 E 0.000 66:24.02 6212.13 N 2499.13 Vi/ 5912680.93 N 361468.79 E 0.(XX) 6684.52 6256,19 N 2557.97 W 5912726.04 N 361410.75 E 0.000 6745.02 6300.26 N 2616.81 W 5912771.16 N :36135Z71 E 0.000 6805.53 634432 N 2675.65 W 5912'816.27 N 3~1294.67 E 0.000 68~B6.03 6371.40 N 2711.81 W 591ZB44.00 N 361259.00 E 0.000 6903.2'[ 6388.38 N 2734.49 W 591ZS61.39 N 361236.63 E 0.0GO 6926.53 6432.45 N 2793.33 W 5912:906.50 N 361178.60 E 0.(XX) 6987.03 6437.50 N 2804).07 W 59 1L>911.67 N 361171.94 E 0.000 6993.96 Ail data is in feet unless othenvise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Weft Reference. The Dogleg Sever~y is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 341.438° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13511.46ft., The Bottom Hole Displacement is 7020.10ft., in the Direction of 336.493° (True}. lS February, 1~- I0:52 Alaska State Plane Zone 3 Badami CPF ' KOP ' Start Dir O 8.000¥1001t- 11700.00ft MD, 9288.371t'TVD Erld Olr, SaN 0 47.316' - 12060.11ll MD, 9~47.63it TVD Ta~et:. 81-I 1 ST Tarffi, 200.00 R~(lus. Geological ~,A-~,~-- A ~-' ~ . Total Depth- 13511-46ff MD, 10531.591t TVD SperrY-Sun Drilling Services Proposal Report for B 1-11 - B 1-11 Wp 10 Badami FOR PERMITTING ONLY Measured Vertical Depth Ined. AzJm. Depth Northlnga Eaetlnge (ti) (fi) {ti) Alaska State Plane Zone 3 Badami CPF Vertical Dogleg Section Rata (ft) ("/lOOtt) 11700.00 42,989 347,473 928~.37 5594,49 N 1810.68 W 5679.85 11800.00 42,888 335.704 9381.82 5658.77 N 1832.04 W 5947.59 8.0oo 11900.00 43.588 324.067 9434.91 5717.68 N 1868.27 W 6014,33 8.000 12000.00 45.815 313.035 9506,21 5770.08 N 1912.70 W 6078.77 8.000 12060.11 47.316 308.829 9,.~7,83 5797.g8 N 1848.10 W 6115.87 8.000 12100,00 47,316 308.829 9574.88 5815.55 N 1969.57 W 6140.00 0.000 12200,00 47,316 306,829 9642.48 S8~9.82 N 2028,41 W 6200.51 0,000 12300,00 47.318 308.829 9710.27 5903.68 N 2087,2~ W 6281.01 0.000 12400.00 47.318 308,829 9778.07 5947.75 N 2146.09 W 6321,51 0.000 12500.00 47.316 308.829 9845.86 5991.81 N 2204.93 W 6382.01 0,000 12800.00 47,316 308,829 9913.66 6035,87 N 2283.77 W 6442.51 0.000 12700.00 47.318 308.829 9981.45 6079,94 N 2322,81 W 6503.02 0.000 12800,00 47.316 308.829 10049.26 8124.00 N 2381.4,5 W 6563.62 0.000 12~00,00 47.315 308,629 10117.05 6168,08 N 2440.29 W 6624,02 0,000 13000.00 47.318 308.829 10184,84 6212.13 N 2499.13 W 6884.52 0.000 13100.00 47.316 306.829 10252,64 6256.19 N 2557.97 W 6745.02 0.000 13200,00 47.316 306.829 10320.43 6300.26 N 2616.81 W 8805.53 0.000 13300.00 47.316 306.829 10388.23 8344,32 N 2875.65 W 6866.03 0,000 13361.46 47,316 308.829 10429.90 6371,40 N 2711,81 W 8903.21 0.000 13400,00 47.318 308,829 10456.03 6;388,38 N 2734,49 W 6926.53 0.000 13500,00 47.318 308.829 10523.82 6432,45 N 2793.33 W 6987.03 0.000 13511,46 47.318 306.829 10531,$9 6437.50 N 2800.07 W 6993.96 0,000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Refererme, Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft, Vertical Section is from Well Referenoe and caloulated along an Azimuth of 341.438° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13511.48ft., The Bottom Hole Displacement is 7020.10ff., in the Direction of 336.493° (True). Comments Measured Depth 11700,oo 12060,11 13511.46 Station Coordinates TVD Northlnga Eaetlngs (n) (fl) (~) 8288.37 5594.49 N 1810.66 W 9547.63 5797,98 N 1946.10 W 10~1.S9 6437.50 N 2800.07 W Comment KOP: Start Dir O 8,000'/100ti: 11700.00fi MD, 9288.37ft TVD End DIr, 8all t} 47.316°: 12060.11ff MD, 9547.63ft TVD Total Depth; 13511,46ft MD, 10531.591t 'I'VD Targets associated with thle we//path Target Name B1-11 ET Target Target Entry Coordi'natee TVD Northlnge Eeeflnga Target Target (ft) (fi) (fi) Shape Type 1042~,~0 6371.40 N 2711.81 W Circle Geological 15 February, l~J~ - 10:$2 .1. Dr/1/Quest Sperry-Sun Drilling Services Proposal Data - B1-11 - B1-11 WplO ~B 11700.00 42.989 347.473 9288.37 ,5594.49 ~; 1810.66 N 5879.85 :~12060.11 360.11 4%.3161 ~0~.8291 9547.63 '259.26,5797.98 ~ 203:'t9 1946.10 ~-135.~1 8.000 263:5~i ' 6115.87 ~'-~ .~'""~'~ ~":-;" .... '~'-~'~';', ~'"~'~ .~'~-~%~--~'~ '"~'~ ~;'~'~1-'-~{~%'~-"~' ~ ~'r~ ' '~ ...... ~ ~ .............. a ~nn~ ............. =nn~ ~ 13361.a6 47.316~ 306.829!L0~29.90~ 882.27i$371.40 ~., 573 .43t 2711. 81, ti~,-765.72i O.O00 O.OOe, 6S ' ~:)R PL:t~ITTtNB ONLY H131951 VENDOR DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT 121797 PYMT HANDL CK121797~ COMMENTS: acc app IN~ INST: s/h ompang permit iication kathg campoa i00.00 At_ASKASTi4 O0 NET 100.00 rilE ATTACHED CHECK IS IN PAYMENT FOR n'EMS DESCRIBED ABOVE. to d~ill · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ ~c3 ,2r"~O INIT CLASS WELL NAME,~,,s,~,' ~_,~-'////"~,' PROGRAM:expE]d~,v~redrll~servDwellboreseg.,-': ann. disposal parareq L~ ./--~j ? GEOL AREA ~;~'Td'~ UNIT# ,/"~:~)2_<:::3~ ON/OFF SHORE ADMINISTRATION 3. 4. 5. 6. 7. 8. 9. 10. 11. PR D E 12. Permit fee attached ....................... Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... N Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~--~ psig. 14. Conductor string provided ................... Y N 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... YN 17. CMT vol adequate to tie-in long string to surf csg ........ ~~q 2_ __ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y 22. N 23. N~r~'~'' 24. N 25. N 26. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones .............. -33. Seabed condition survey (if off-shore) ............ /Y N 34. Contact name/phone for we,ekly,pro[lress reports ..... /. Y N lexp~ora~ory only] GEOLOGY: ENGINEERING: COMMISSION' BEW~,,~r~::~ DWJ ~ JDH ~ R N C~:;~ CO Commentsllnstructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Apr 06 11:19:45 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/06- Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER BADAMI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Bi-llA 500292282901 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 06-APR-98 MWD RUN 5 MWD RUN 6 MWD RUN 7 AK-VC-80075 AK-VC-80075 AK-VC-80075 S.NEUBAUER M.CADY M.CADY N.SCALES N.SCALES N.SCALES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MWD RUN 9 MWD RUN 14 AK-VC-80075 AK-VC-80075 AK-VC-80075 M.CADY M.CADY G. TOBIAS N.SCALES N.SCALES D. MASKELL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 15 AK-VC-80075 S. NEUBAUER D. MASKELL MWD RUN 16 AK-VC-80075 M. HALL · ~ D. MASKELL SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 09N 20E 3854 156 53.90 52.40 18.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 5059.0 8.500 7.000 10605.0 6.000 13375.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-4 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 5-9 AND 12-15 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 4. MWD RUNS 11, 12, AND 13 ARE NOT PRESENTED DUE RESPECTIVELY TO TOOL LOSS, INABILITY TO KICKOFF CEMENT PLUG, AND MWD FAILURE. 5. MWD RUN 16 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) 6. EWR4 DATA FROM 11659'MD, 9258'TVD TO 12224'MD, 9670'TVD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE GOING IN THE HOLE PRIOR TO MWD RUN 16. THIS DATA IS PRESENTED WITH THE MERGED RUN 16 DATA. 7. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN K LEMLEY OF BP EXPLORATION (ALASKA), INC. AND A TURKER OF SPERRY- SUN DRILLING SERVICES ON 3/23/98. THIS DATA IS CONSIDERED PDC. 8. MWD RUNS 1-9 AND 14-16 REPRESENT WELL BI-llA WITH API#: 50-029-22829-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13375'MD, 10475'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH STOP DEPTH 5007.0 13327.5 5076.5 13375.5 11659.0 13334.5 11659.0 13334.5 11659.0 13334.5 11659.0 13334.5 11659.0 13334.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD 5 MWD 6 MWD 7 MWD 8 MWD 9 MWD 14 MWD 15 MWD 16 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 MERGE BASE 5075.0 10616.0 10616.0 10986.0 10986.0 11222.0 11222.0 11243.0 11243.0 11793.0 11793.0 11845.0 11845.0 12224.0 12224.0 13375.0 BIT RUN NO MERGE TOP Depth Units ....................... Datum Specification Block sub-type...0 Rep Code Offset Channel Name Service Order Units Size Nsam DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OH~M 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 5007 13375.5 9191.25 16738 5007 GR 13.59 111.628 66.6629 16642 5007 ROP 1.06 4117.78 163.451 16578 5076.5 RPX 4.3892 125.526 12.059 3352 11659 RPS 4.3871 90.705 10.9887 3352 11659 RPM 4.2132 109.187 10.8019 3352 11659 RPD 4.7866 194.468 13.4606 3352 11659 FET 0.1744 147.695 12.3746 3352 11659 Last Reading 13375.5 13327.5 13375.5 13334.5 13334.5 13334.5 13334.5 13334.5 First Reading For Entire File .......... 5007 Last Reading For Entire File ........... 13375.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5007.0 ROP 5076.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10547.0 10615.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 26-JAN-98 MSC 2.04 MEMORY 10616.0 5075.0 10616.0 41.4 46.6 TOOL NUMBER NGP SPC 318 8.500 8.5 NON DISPERSED 9.80 460.0 8.2 90O 5.3 .000 .000 .000 .000 .0 53.9 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5007 10615.5 7811.25 11218 5007 GR 13.59 105.13 59.8569 11081 5007 ROP 7.83 4117.78 227.301 11079 5076.5 Last Reading 10615.5 10547 10615.5 First Reading For Entire File .......... 5007 Last Reading For Entire File ........... 10615.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10547.5 10921.0 ROP 10616.0 10958.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMI/M ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 30-JAN-98 MSC 2.04 MEMORY 10986.0 10616.0 10986.0 39.6 40.7 TOOL NUMBER NGP SPC 318 6.000 6.0 KCL/POLYMER 11.10 460.0 9.2 10100 6.6 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel 49.2 DEPT FT 4 1 68 GR MWD 6 AAPI 4 1 68 ROP MWD 6 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 10547.5 10985 10766.2 876 GR 41.64 95.85 74.1952 748 ROP 7.86 204 40.687 739 First Reading 10547.5 10547.5 10616 Last Reading 10985 10921 10985 First Reading For Entire File .......... 10547.5 Last Reading For Entire File ........... 10985 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Cormment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10921.5 11156.0 ROP 10987.5 11222.0 $ LOG HEADER DATA DATE LOGGED: 01-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC DOWNHOLE SOFTWARE VERSION: 2.04 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11222.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10986.0 11222.0 39.6 45.1 TOOL NUMBER NGP SPC 217 6.000 6.0 KCL/POLYMER 12.90 54.0 8.0 14000 4.7 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 51.6 First Last Name Min Max Mean Nsam DEPT 10921.5 11222 11071.8 602 GR 71.37 91.31 82.4613 470 ROP 8.36 49.34 15.4829 470 Reading 10921.5 10921.5 10987.5 Reading 11222 11156 11222 First Reading For Entire File .......... 10921.5 Last Reading For Entire File ........... 11222 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Conunent Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11156.5 11177.0 ROP 11225.5 11242.5 $ LOG HEADER DATA DATE LOGGED: 02-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC DOWNHOLE SOFTWARE VERSION: 2.04 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11243.0 TOP LOG INTERVAL (FT) : 11222.0 BOTTOM LOG INTERVAL (FT): 11243.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.1 MAXIMUM ANGLE: 45.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH:' MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP SPC 318 6.000 6.0 KCL/POLYMER 12.90 61.0 8.1 12000 4.9 .000 .000 .000 .000 56.1 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11156.5 11242.5 11199.5 173 11156.5 GR 84.71 91.25 86.6462 42 11156.5 ROP 5.25 31.86 11.6421 35 11225.5 Last Reading 11242.5 11177 11242.5 First Reading For Entire File .......... 11156.5 Last Reading For Entire File ........... 11242.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUP~V~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11177.5 11793.0 ROP 11243.0 11793.0 $ LOG HEADER DATA DATE LOGGED: 07-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC DOWNHOLE SOFTWARE VERSION: 2.04 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 13167.0 TOP LOG INTERVAL (FT): 11243.0 BOTTOM LOG INTERVAL (FT): 13167.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.6 MAXIMUM ANGLE: 45.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER NGP SPC 318 6.000 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OH~94) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.0 KCL/POLYMER 12.60 58.0 8.8 20000 5.2 .000 .000 .000 .000 58.6 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11177.5 11793 11485.2 1232 11177.5 GR 66.8 94.52 82.2668 1232 11177.5 ROP 4.73 69.43 43.9657 1101 11243 Last Reading 11793 11793 11793 First Reading For Entire File .......... 11177.5 Last Reading For Entire File ........... 11793 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW ~CWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 11796.0 11845.0 $ LOG HEADER DATA DATE LOGGED: 21-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC DOWNHOLE SOFTWARE VERSION: 2.04 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11845.0 TOP LOG INTERVAL (FT): 11793.0 BOTTOM LOG INTERVAL (FT): 11845.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.5 MAXIMUM ANGLE: 42.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): TOOL NUMBER NGP SPC 217 6.000 6.0 KCL/POLYMER 12.40 55.0 11.4 18000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.8 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 14 FT/H 4 1 68 4 2 61.1 First Name Min Max Mean Nsam Reading DEPT 11796 11845 11820.5 99 11796 ROP 1.06 21.24 6.52768 99 11796 Last Reading 11845 11845 First Reading For Entire File .......... 11796 Last Reading For Entire File ........... 11845 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Con~nent Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11793.5 ROP 11847.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12158.0 12223.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 23-FEB-98 MSC 2.04 MEMORY 12224.0 11845.0 12224.0 38.1 48.5 TOOL NUMBER NGP SPC 217 6.000 6.0 KCL/POLYMER 12.40 63.0 11.3 17000 3.4 .000 .000 .000 .000 60.6 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... ' Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 15 AAPI 4 1 68 4 2 ROP MWD 15 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11793.5 12223 12008.2 860 11793.5 GR 36.54 88.45 80.6368 730 11793.5 ROP 8.35 381.25 33.7549 752 11847.5 Last Reading 12223 12158 12223 First Reading For Entire File .......... 11793.5 Last Reading For Entire File ........... 12223 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 11659.0 13334.5 RPD 11659.0 13334.5 RPM 11659.0 13334.5 RPS 11659.0 13334.5 RPX 11659.0 13334.5 GR 12158.5 13327.5 ROP 12223.5 13375.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 27-FEB-98 MSC 2.04 MEMORY 13375.0 12224.0 13375.0 41.6 48.7 TOOL NUMBER P0921SP4 P0921SP4 6.000 6.0 KCL/POLYMER 12.40 590.0 9.5 15400 3.6 .560 .289 .150 .760 70.3 HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 Name Service Order Units Size Nsam DEPT FT 4 1 68 GR MWD 16 API 4 1 68 ROP MWD 16 FT/H 4 1 68 RPX MWD 16 OHMM 4 1 68 RPS MWD 16 OHMM 4 1 68 RPM MWD 16 OHMM 4 1 68 RPD MWD 16 OHMM 4 1 68 FET MWD 16 HOUR 4 1 68 Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 11659 13375.5 12517.2 3434 GR 28.751 111.628 80.3845 2339 ROP 3.6106 479.004 34.26 2284 RPX 4.3892 125.526 12.059 3352 RPS 4.3871 90.705 10.9887 3352 RPM 4.2132 109.187 10.8019 3352 RPD 4.7866 194.468 13.4606 3352 FET 0.1744 147.695 12.3746 3352 First Reading 11659 12158.5 12223.5 11659 11659 11659 11659 11659 Last Reading 13375.5 13327.5 13375.5 13334.5 13334.5 13334.5 13334.5 13334.5 First Reading For Entire File .......... 11659 Last Reading For Entire File ........... 13375.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/04/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/04/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
