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213-065
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 9, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-114 PRUDHOE BAY UN BORE Z-114 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/09/2024 Z-114 50-029-23490-00-00 213-065-0 G SPT 6348 2130650 3000 1867 1872 1867 1865 0 0 0 0 OTHER P Sully Sullivan 2/19/2024 MIT-IA to evaluate T x IA communication and AA request with MAIP of 3000 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE Z-114 Inspection Date: Tubing OA Packer Depth 546 3308 3279 3269IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240219155738 BBL Pumped:4.7 BBL Returned:3.3 Tuesday, April 9, 2024 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Injector Z-114 (PTD #213065) AA review for continued injection Date:Wednesday, February 21, 2024 7:49:36 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, February 21, 2024 6:05 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector Z-114 (PTD #213065) AA review for continued injection Mr. Wallace, WAG Injector Z-114 (PTD #213065) passed AOGCC MIT-IA on 02/19/24 and an AA for continued injection was submitted on 02/20/24. AOGCC granted permission to keep the well on injection while the AA is reviewed. The under evaluation clock has been reset. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, January 24, 2024 2:08 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-114 (PTD #2130650) Suspected TxIA communication Mr. Wallace, WAG Injector Z-114 (PTD #2130650) IA casing pressure was noted on TIO plot with an increasing trend on MI with no rate or temperature change. The IA was bled on 01/24/24 with partial gas returns. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Change out packing on DGLVs 3. Well Integrity: Further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Injector Z-114 (PTD #2130650) Slow TxIA communication Date:Tuesday, February 20, 2024 2:52:50 PM From: Wallace, Chris D (OGC) Sent: Tuesday, February 20, 2024 2:51 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: Injector Z-114 (PTD #2130650) Slow TxIA communication Ryan, We have received the admin approval request. You are approved for continued injection while we process the AA. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, February 20, 2024 11:14 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector Z-114 (PTD #2130650) Slow TxIA communication Mr. Wallace, WAG Injector Z-114 (PTD #2130650) a tubing pack off test passed on 01/25/24 and dummy gas lift valves with extended packing were set on 02/06/24. AOGCC MIT-IA passed to 3269 psi on 02/19/24 (see attached). An AA request for continued injection with slow TxIA was submitted to AOGCC 02/20/24. The original under evaluation clock is set to expire on 02/21/24. We would like to request permission to keep the well on injection while the AA is reviewed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, January 24, 2024 2:08 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-114 (PTD #2130650) Suspected TxIA communication Mr. Wallace, WAG Injector Z-114 (PTD #2130650) IA casing pressure was noted on TIO plot with an increasing trend on MI with no rate or temperature change. The IA was bled on 01/24/24 with partial gas returns. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Change out packing on DGLVs 3. Well Integrity: Further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2130650 Type Inj G Tubing 1867 1872 1867 1865 Type Test P Packer TVD 6348 BBL Pump 4.7 IA 546 3308 3279 3269 Interval O Test psi 3000 BBL Return 3.3 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp North Slope LLC Prudhoe Bay / PBU / Z Pad Sully Sullivan Ryan Holt 02/19/24 Notes:AOGCC MIT-IA Well under eval for slow TxIA, AA request max anticipated injection pressure 3000 psi Notes: Notes: Notes: Z-114 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)MIT PBU Z-114 02-19-24 (002) From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: UNDER EVALUATION: Injector Z-114 (PTD #2130650) Suspected TxIA communication Date:Monday, January 29, 2024 10:02:44 AM Attachments:Raw Data.xlsx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 25, 2024 1:06 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: UNDER EVALUATION: Injector Z-114 (PTD #2130650) Suspected TxIA communication Mr. Wallace, There are multiple reasons why an injector may require a bleed that range from thermal effects, injection rate changes and the one you are interested in, signs of pressure communication. From a well integrity UIC monitoring standpoint we get multiple automated lists of injectors every day. The first consists of wells that have at least one annulus pressure above 250 psi and either the injection pressure/ inner annulus differential pressure are within 250 psi or the inner annulus pressure/ outer annulus pressure are within 100 psi. The second list flags injectors that have an inner annulus pressure > 1000 psi. The reason for the list of injectors with IAP > 1000 psi is to proactively identify wells that have high injection pressures that may be exhibiting signs of inner annulus re- pressurization. All of these reports are reviewed by the Well Integrity department daily to identify any injectors that require an annulus bleed. There is a high turnover rate of wells in both automated sections of the report due to factors such as changes in injection rate, injection temperature, injection pressure and changes in annular fluid volume from testing. As a result, this requires annular bleeding to bring pressures back to their prescribed differential minimums. In short, our recommended practice, for injectors, is to maintain a pressure differential of 250 psi between the Tubing x IA, 100 psi between the IAxOA and maintain IA pressure < 1000 psi. The pressure differential piece to the recommended practice is not always achievable due to many factors such as low injection pressure, sporadic temperature or rate changes, etc. In these cases, we still maintain a pressure differential between the tubulars that prove no pressure communication is exhibited between the strings. When an injector is bled, the bleed is captured by manual input into the well pad operator’s software. If DHD performed the bleed, it is captured in a well service report along with the well pad operator entering it into the software. A daily automated report is generated that identifies any injectors that have had a pressure bleed in the past 7 days and any injectors that have had two or more pressure bleeds in the past 30 days. These reports are also reviewed by the Well Integrity department to identify any injectors that are potentially exhibiting signs of pressure communication across tubulars. For this well in particular, I have attached the one year’s worth of graphical and raw data you requested. Up until the IA pressure increase that started around December 14, 2023 there were no prior anomalous pressure trends. The increasing pressure trend was first identified on December 26, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2023 when the IA pressure reached 1000 psi. This triggered the well to populate in the report mentioned above because the IAP was >1000 psi. When this was reviewed by the Well Integrity department, it was noted that an injection temperature increase was observed on December 20, 2023 and a diagnostic bleed was scheduled and performed the night of December 29, 2023. There was also a significant injection rate increase between December 29, 2023 and December 30, 2023 (I have attached an injection plot as well). The bleed on December 29, 2023 was performed by DHD and was entered into a well service report on that date, but was not entered in into the operator’s software until December 30, 2023 so it looks like two bleeds according to the graph. This bleed was not reported to the AOGCC because it was not clear if the pressure increase was due to pressure communication or simply tied to thermal and/or injection rate changes. Shortly after the bleed, the IA pressure increased but was coupled with another temperature increase on January 5, 2024. All the while, another injection rate increase was also observed around January 5, 2024. The IA pressure then seemed to stabilize from January 6, 2024 – January 13, 2024 so it was still not evident of any pressure communication. When the IA pressure began to climb again, it was not discovered by Well Integrity until the IA pressure exceeded 1000 psi and it was flagged in the automated reports. At that time, a second diagnostic bleed was scheduled to confirm the re-pressurization and was performed on January 24, 2024 and reported to the AOGCC on the same day. I hope this helps answer your questions. Please call or email back if you require any further information. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, January 24, 2024 4:25 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: UNDER EVALUATION: Injector Z-114 (PTD #2130650) Suspected TxIA communication Ryan, When I look at the TIO I see large IA increases daily from December 14, 2023 and a bleed (or 2) on or around December 30, 2023. This is immediately followed with increasing IA pressures through to this report. The question is why wasn’t this discovered/reported before now? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. What is the protocol of instituting a bleed on an injector? What reporting was associated with the bleeds of December 30 and what was the decision process and expectations? Have there been similar IA increases and bleeds for this well? Please provide a years’ worth of data (graphical and raw data in excel). Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, January 24, 2024 2:08 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-114 (PTD #2130650) Suspected TxIA communication Mr. Wallace, WAG Injector Z-114 (PTD #2130650) IA casing pressure was noted on TIO plot with an increasing trend on MI with no rate or temperature change. The IA was bled on 01/24/24 with partial gas returns. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Change out packing on DGLVs 3. Well Integrity: Further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 Ytll:2-14 R nl PIN —P.MIP —pW —YI =G� —Gn a� zAtl no to to no Plot �naoe —o. • aw Iby ♦ k . xo to no, wll ♦ a.,Ewl • MANto IA P-pi_ -MAN_W to p A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re gg� r DATE: Wednesday, October 6, 2021 P.I. Supervisor !'` �� z l SUBJECT: Mechanical Integrity Tests 1 Hilcorp North Slope, LLC Z-114 FROM: Bob Noble PRUDHOE BAY UN BORE Z-114 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE Z-114 API Well Number 50-029-23490-00-00 Inspector Name: Bob Noble Permit Number: 213-065-0 Inspection Date: 10/3/2021 Insp Num: mitRCN2 11004095951 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z-114 Type Ind � G -I, TVI) 6348 Tubing 2222 2224. 2225 2226 . PTD 2130650' Type Test i SPT- Test psi 1587 IA 245 2929 - 2916. 2910 + BBL Pumped: 2.7 - '.BBL Returned: 2.7 - OA 0 2- 1- 1 - Interval 4YRTST p/F P Notes: Wednesday, October 6, 2021 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:213-065 6.50-029-23490-00-00 PRUDHOE BAY, BOREALIS OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10245 10152 6786 9667 None None 6348 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 20" 48 - 128 48 - 128 Surface 3139 9-5/8" 48 - 3187 48 - 3182 5750 3090 Intermediate Production 10190 7" 45 - 10235 45 - 6863 7240 5410 Perforation Depth: Measured depth: 9858 - 9987 feet True vertical depth:6514 - 6633 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 43 - 9791 43 - 6455 9667 6348Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Packer Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): 180-bbls diesel to clear tubing of schmoo Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 212350 513 0 3998 2915 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brodie Wages David.Wages@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5006 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured6873 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 9858 - 9908 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028262 PBU Z-114 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:02 am, Mar 23, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.03.22 21:14:24 -08'00' Stan Golis (880) SFD 3/23/2021MGR24MAR2021DSR-3/23/21 RBDMS HEW 3/25/2021 ACTIVITY DATE SUMMARY 3/9/2021 ***WELL INJECTING ON ARRIVAL*** PULLED 4-1/2" MCX @ 1995' MD (sn: m-31) DRIFT TBG w/ 20' x 3.16" DMY GUNS TAG TD ~9948' SLM(poor action/jar free) DRIFT TBG TO XN NIP @ 9774' MD w/ 3.80" G-RING FOR CORRECTION (+45' cf) LRS PUMPED 180 BBLS DIESEL TO FLUSH STICKY SHMOO @ TAG DEPTH DRIFT TBG w/ 20' x 3.16" DMY GUNS & 1.5" SAMPLE BAILER TO HARD TD TO 9948' SLM (9993'MD to 9893' MD +300lbs PU Weight, thick shmoo in bailer) ***JOB COMPLETE, WELL LEFT SI, DSO NOTIFIED OF STATUS*** 3/9/2021 T/I/O=1700/47/0 LRS Unit #72 (Assist Slickline) Pumped 180 bbl's of diesel down TBG to displace schmoo. FWHPs=625/30/0 3/14/2021 ...Well shut in on arrival... (HES EL - adperf a sands) PERFORATE 9,972'-9,987' WITH 15' x 2-7/8" 17.5 GR MAXFORCE HMX CHARGES, 6 SPF, 60 DEGREE PHASING HSC LOADED. API 19 PENETRATION = 38.6", ENTRANCE HOLE = 0.37". CORRELATED TO BP PDCL 22-SEP-2015. ***Job Complete. Well shut in on departure. WPO to POI.*** Daily Report of Well Operations PBU Z-114 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e-7, DATE: Thursday,October 12,2017 P.I.Supervisor 1 _l�1 !0(t6(e 7 SUBJECT: Mechanical Integrity Tests t BP EXPLORATION(ALASKA)INC. Z-114 FROM: Lou Laubenstein PRUDHOE BAY UN BORE Z-114 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ��— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE Z-114 API Well Number 50-029-23490-00-00 Inspector Name: Lou Laubenstein Permit Number: 213-065-0 Inspection Date: 10/8/2017 Insp Num: mitLOL171008133224 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well z-114 ' Type Inj W TVD 6348 " Tubing 1312 1314 ' 1313 - 1312 - PTD 2130650 Type Test SPT Test psi 1587 IA 798 2502 ' 2492 2488 - BBL Pumped: 13 BBL Returned: 1.5 OA 345 519 . 517 513 Interval 4YRTST IP/F P Notes: Good test SCANNED Thursday,October 12,2017 Page 1 of 1 2 (3 -i4 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, April 14, 2014 9:14 AM To: 'Ryan.ciolkosz@bp.com' Cc: Guhl, Meredith D (DOA) Subject: PBU Z-114 Perforation Date Ryan, While reviewing the Well Completion Report submitted for PBU Z-114, I noticed that BP provided a completion date of September 23, 2013 on that report. The daily Operations Summary Reports attached to the report end on July 24, 2013. I checked AOGCC's well history files and found no information beyond July 24, 2013; nothing to support the September completion date. Could BP please submit daily reports for all operations conducted on PBU Z-114 subsequent to July 24, 2013? Could BP also provide the date that the well was perforated between 9858' and 9908' measured depth? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 AOGCC: 907-279-1433 1 ' STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION On 2 2 2013 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class Act 20AAC 25.105 20AAC 25.110 0 Exploratory tr Ig phic 0 GINJ 0 WINJ ®WAG• 0 WDSPL 0 Other No.of Completions One • 0 Development ®Service, 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 'µ 12. Permit to Drill Number: BP Exploration(Alaska) Inc. -91 12013 7/ZL4/1 =" 213-065 ' 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 7/7/2013 ' 50-029-23490-00-00• 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 7/16/2013 ' PBU Z-114 • 4564'FSL,3480' FEL, Sec. 19,T11 N, R12E, UM 8. KB(ft above MSL): 15.Field/Pool Pool(s)of Productive Horizon: ) 102.05' ( ) 4604' FSL, 1855' FEL, Sec. 18,T11 N, R12E, UM , GL(ft above MSL): 54.5' ' Prudhoe Bay/Borealis Oil Pool Total Depth: 9.Plug Back Depth(MD+TVD) 4745' FSL, 1809' FEL, Sec. 18,T11 N, R12E, UM 10152' 6786' ' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 599193 y- 5959360 Zone- ASP4 10245' 6873' • ADL 028262 ' TPI: x- 600726 y- 5964701 Zone- ASP4 ' 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 600770 y- 5964842 Zone- ASP4 None 18.Directional Survey: ®Yes ❑No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1811' 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: MWD/GR/RES, MWD/GR/RES/NEU/DEN, USIT, CBL N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 129# X-56 48' 128' 48' 128' Driven 9-5/8" 40# L-80 48' 3187' 48' 3182' 12-1/4" 1758 sx LiteCrete, 339 sx Class'G' 7" 26# L-80 46' 10235' 46' 6863' 8-3/4" 567 sx LiteCrete, 183 sx Class'G' 24. Open to production or injection? ®Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ (MD+TVD of Top&Bottom;Perforation Size and Number): ND) 2-7/8"Gun Diameter,6 spf x_ 4-1/2", 12.6#, L80 9791' 9667'/6348' ' L;CM Lrji64.' Cirr- '. '71p-1113 w 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9858'-9908' 6515'-6560' . ;+ t�a1;IL;:' 1 WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2200' Freeze Protect w/17 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc October 15,2013 Water Injection Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate • 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS OCT 2 9 20t Form 10-407 Revised 10/2012 CONTINUED ON REVERSE `�'/ �' / Submit Original Only Gl-I( PN �` c/4 29. GEOLOGIC MARKERS(List all formations an :ers encounter 30. FORMATION TESTS NAME MD ND Well Tested? LI Yes ®No Permafrost Top 48' 48' If yes,list intervals and formations tested,briefly summarizing test Permafrost Base 1860' 1859' results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 3213' 3208' None Ugnu M 4509' 4175' Schrader Bluff N 5185' 4440' Schrader Bluff 0 5689' 4633' Base of Schrader Bluff/Coleville 6647' 5012' HRZ 9615' 6306' Kalubik 9812' 6473' Kuparuk C 9856' 6513' • LCU/Kuparuk B 9908' 6560' Kuparuk A 9957' 6605' Miluveach 10031' 6674' Formation at Total Depth: Miluveach 10031' 6674' 31.List of Attachment: Summary of Daily Drilling Reports, LOT/FIT Summary,Well Schematic Diagram, Surveys,Cement Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Ciolkosz,564-5977 Email: Ryan.Ciolkosz@bp.com Printed Name: Joe Lastu Title: Drilling Technologist Signature: A Phone 564-4091 Date: Ic/4/I 3 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only TRt-��-=• 4-1/16"CNV VsaLHEAD= FMC Z-114 _1 1 w SAF DTES: CHROME NIPPLES I ACTUATOR= CNV LEO i� OKB.ELEV= 102.05' --l BE.ELEV= 54.5' KOP= 2767' Max Angle= 69"@-53-5-6'.. Datum M)= 1 62' I I ( 1995' —I4-112"HES X NP(9CR),D=3.813" Datum TVD= 6600'SS 20"CONDUCTOR, 129#,X-56,D=19.124" 128' GAS LFT MANDRELS ST MD l V D DEV TYPE VLV LATCH FORT DATE hi 3 2843 2842 7 KBG DMY BK 0 10/01/13 9-5/8"CSG,40#,L-80 BTC, U=8.835" H 3187' 2 6670 5021 68 KBG DMY BK 0 07/23/13 1 9600 6294 38 KBG DMY BK 0 10/01/13 ESTIMATED TOP OF CEMENT — 3884' — 4' *. * + 9636' 44-112"HES X NIP(9CR),ID=3.813"I II Minimum ID = 3.725" @ 9774' 4-1/2" HES XN NIPPLE (9CR) 9667' --{7"X 4-1/2"HES TNT PKR,U=3.870" 44 74 4 `}► 'y� 9704' H14-1/2"HES X Nio(9CR),ID=3.813" 1 9774' —I4-1/2"HES XN NIP(9CR),ID=3.725" * / \ 9791' —14-1/2"WLEG,U=3.958" 4-1/2"TBG, 12.6#,L-80 TCA, H 9791' .A .0152 bpf,D=3.958" ? —I EMD TT LOGGED NOT LOGGED +. Y. 4 �7 ",i litli - 9802' - i2 10'MARKER JTS w/RA TAG PERFORATION SUMMARY * -4 v. * REF LOG: SLB MSIP/A3C ON 7/22/13 ANGLE AT TOP PERF:25"@ 9858' * Note:Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz SHOT SQZ t* 2-7/8" 6 9858-9908 0 09/23/13 v. 7.. ,i. ♦. tf *. t . ,i. o. ,r. YA PBTD 10157 .'....'.,.,... 7"CSG,26#,L-80 VAM TOP I-IC, —I 10235' .0383 bpf,D=6.276" ' DATE REV BY I COMMENTS DATE REV BY COAT+BJTS PRUDHOE BAY tJNTE 07/26/13 PKR273 INTIAL COMPLETION WELL: Z-114 08/01/13 JMD DRLG HO CORRECTIONS 1U MT No:'2130650 09/18/13 WKF/JMJ GLV C/O(09/15/13) API No: 50-029-23490-00 10/04/13 SET/JMJ ADPERFS(09/23/13) SEC 19,T11 N,R12E,716'FNL&1472'FWL 10/04/13 GJB/JM) GLV 00(10/01/13) 10/09/13 PJC PERFORATION CORRECTION BP Exploration(Alaska) 0 co W d 6 J iT C ' -Ch. 0 v 0 CC I C N O W O O 53 0) 'ill— O 0 m D O .. a d 2 0 a O L o O U 0 a N o o H Z H -O W OCf O Q w o) 0 o ),, g a ,— CO 0 W U `n Z C d N U) Q' co a J O co— N 2 -'14cn (n > p > O` m 0 O '- _ 0 N -0 lL O -0 LL- O Fc 6 U -6 U O O O Q] 0 N N O IL. V a7 I� W 2 a) N 5 a) .) 5 N CD O c') O X• N W N W O O O m O (o E' a) N "6 N N J > L' a) z' N z' a) z• N J rO fo x C r.( a) N N N x N N N ? 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N D a) O U c.N O O WQ Z r) Y o < v `) a v m N N a) ,-T, N d N ^ N m m E F a Z a a a O a) a) a) r Z > 0 tj fa 0) .0 t (5 & Q' Q N t m ul J N aO H = m O o O_ O u - 0 I z d 0 c a) O of .2 v) N 3 C) Z- N U O a o m U 0 > Z a z Z =O U C7 o c 2 W W z y 0 E N m ix J H C a) — 0 J C V M L y VI 1 FeN Z N C o N ai m U IX U aa) J m co Y o Z o 0 O CD La U da o C d 0.T O = O .. N = .O- o LL O U ~ ` C d 3 3 oo p o ° > o a ai E ct m -o v p- a UMW U D T E a) m c o w o a N - F= 0 0 D co 0 co H I BP AMERICA LOT / FIT Summary Well Name: Z-114 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 07/13/13 LOT 3,187.00 3,185.34 9.20 1,320.00 2,842.35 17.18 Page 1 of 1 North America-ALASKA-BP Page 1 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 7/2/2013 17:00 - 22:30 5.50 RIGD P PRE BEGIN DON EVENT WITH PARKER RIG 273 AT 17:00 ON 7/2/2013. R/D RIG FLOOR.R/D MUD MODULE. BRIDLE UP TOP DRIVE. PARK IRON DERRICK MAN. PARK FORUM CRANE. UN-PIN TOP DRIVE TORQUE TUBE. SECURE DRILLPIPE IN PIPE BARN. REMOVE ROOFTOP WALK WAYS. PREPARE MUD MODULE MOVING SYSTEM FOR MODULE MOVE. 22:30 - 00:00 1.50 RIGD P PRE MOVE CATTLE CHUTE AND SKID RIG FLOOR. 7/3/2013 00:00 - 03:00 3.00 RIGD P PRE PREPARE TO PULL MUD MODULE AWAY FROM DRILL MODULE. PREPARE RIG FLOOR AND COMPLETE CHECKLIST FOR LAYING OVER MAST. -CHANGEOUT SHOE BOLTS/NUTS ON DRILLER'S SIDE DERRICK A-LEG 03:00 - 04:00 1.00 RIGD P PRE PULL MUD MODULE AWAY FROM DRILL MODULE,STAGE AT PAD ENTRANCE. 04:00 - 05:00 1.00 RIGD P • PRE LOWER MAST FOR RIG MOVE -409 KLBS SLACKOFF WEIGHT RIGHT ABOVE MAST RACK 05:00 - 15:00 10.00 MOB P PRE MOVE MUD MODULE(2.8 MMLBS)FROM W PAD TO Z PAD,5 MILES. STAGE ON PAD, AWAITING OTHER MODULES. -CH2M HILL CRANE LIFT WELLHOUSE OFF W-51,TRANSPORT TO Z PAD,AND SPOT OVER Z-114 15:00 - 00:00 9.00 MOB P• PRE BASED ON ASSESSMENT OF ACCESS ROADS AFTER MOVING MUD MODULE,ELECT TO LAY RIG MATS ON ENTIRE ACCESS ROAD. • -DRILL MODULE(3.5 MMLBS)AND UTILITY MODULE(2.4 MMLBS)STAGED AT W PAD ENTRANCE,READY TO MOVE. 7/4/2013 00:00 - 17:00 17.00 MOB P PRE MOVE DRILL MODULE FROM W PAD TO Z PAD -LEAP FROG RIG MATS ON W PAD ACCESS ROAD FOR 100%MAT COVERAGE DUE TO ROAD STABILITY CONCERNS. -MUD MODULE REMAINS STAGED AT Z PAD 17:00 - 22:30 5.50 MOB P PRE SPOT DRILL MODULE OVER Z-114 -NIPPLE UP FIRST TWO SECTIONS OF HIGH PRESSURE RISER TO ASSIST WITH CENTERING RIG,USING PLUMB BOB. -22:30: RIG ON LOCATION WHEN FIRST MODULE SPOTTED 22:30 - 00:00 1.50 MOB P PRE RIG CREW TRAVELS BACK TOW PAD AND PREPARES UTILITY MODULE FOR MOVING. 7/5/2013 00:00 - 03:00 3.00 MOB P PRE MOVE UTILITY MODULE HALFWAY DOWN W PAD ACCESS ROAD. STAGE ON ROAD. 03:00 - 09:30 6.50 MOB P PRE RIG CREW TRAVELS TO Z PAD. LEVEL DRILL MODULE AND SPOT MUD MODULE UP AGAINST DRILL MODULE. -TOOL SERVICE WORKING ON LAYING OUT MATS ON REMAINDER OF W PAD ACCESS ROAD PRIOR TO CONTINUING ON WITH UTILITY MODULE. Printed 8/5/2013 1:41:31PM North America-ALASKA-BP Page 2 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 09:30 - 15:00 5.50 MOB P PRE MOVE UTILITY MODULE FROM HALFWAY DOWN W PAD ACCESS ROAD TO Z PAD. -PART OF RIG CREW REMAINS ON Z PAD- MAKE UP INTERCONNECTS AND NIPPLE UP DIVERTER HIGH PRESSURE RISERS. _ 15:00 - 16:00 1.00 MOB P PRE SPOT UTILITY MODULE UP AGAINST DRILL MODULE. RAISE ALL THREE DRIVING CABS TO STORAGE POSITION. 16:00 - 21:00 5.00 RIGU P PRE GENERAL RIG UP OPERATIONS. -SET ROOF CAPS AND RIG UP MODULE INTERCONNECTS -NIPPLE UP HIGH PRESSURE RISERS AND DIVERTER. 21:00 - 23:00 2.00 RIGU P PRE RAISE MAST. SKID RIG FLOOR AND CATTLE CHUTE INTO DRILL POSITION. RAISE PIPE CAT -MAST PICKUP WEIGHT OFF STAND=545 KLBS. 23:00 - 00:00 1.00 RIGU P PRE GENERAL RIG UP OPERATIONS -RIG UP RIG FLOOR -FUNCTION TEST RIG ESD(PASS) TAKE ON 8.5 PPG DRILPLEX MUD 7/6/2013 00:00 - 07:00 7.00 MOB P PRE GENERAL RIG UP OPERATIONS BRIDLE DOWN,PIN TORQUE TUBE AND TRAVELLING BLOCK TO TOP DRIVE. -PREPARE IRON DERRICKMAN AND RIG UP RIG FLOOR- -TORQUE HIGH PRESSURE RISER AND DIVERTER BOLTS I-LAYOUT ROOF WALKWAYS -NIPPLE UP FLOW RISER. RIG UP KNIFE VALVE CONTROL LINES. -TAKE ON 8.5 PPG DRILPLEX MUD 07:00 - 21:00 14.00 MOB P PRE TROUBLESHOOT AND REBUILD ACCUMULATOR AIR PUMPS. SIMOPS: -BUILD(28)4"DP STANDS AND(6)4"HWDP STANDS WITH OFFLINE STANDBUILDING EQUIPMENT. -COMPLETE TOTCO DRILLING INSTRUMENTATION CALIBRATION AND FUNCTION TEST -LOAD BHA COMPONENTS UP TO RIG FLOOR AND INTO PIPE BARN -ADD TWO ADDITIONAL SECTIONS TO DIVERTER TO EXTEND PAST IGNITION SOURCE -PRESSURE TEST MUD LINE TO 4000 PSI -TAKE ON REMAINDER OF 8.5 PPG DRILPLEX MUD(1160 TOTAL BBLS LOADED IN PITS) -COMPLETE KNIFE VALVE/ANNULAR PREVENTER FUNCTION TEST,CLOSING TIME =40 SEC -HOLD DIVERTER(D3)/RIG EVACUATION/H2S DRILL(BUCKLER CREW) ACCEPT PARKER 273 RIG AT 21:00 21:00 - 23:00 2.00 RIGU P PRE CENTER TOP DRIVE OVER WELL CHANGEOUT TRAVELLING CABLES ON PIPE CAT. Printed 8/5/2013 1:41:31 PM North America-ALASKA-BP Page 3 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL©102.05usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 RIGU P PRE DIVERTER/RIG EVACUATION DRILL WITH AAR (HUNDLEY CREW)AND PRE-SPUD MEETING (BOTH CREWS) 7/7/2013 00:00 - 03:00 3.00 RIGU N RREP 128.00 PRE IADC CODE 8 NPT: CENTER TOP DRIVE •OVER WELL. CHANGEOUT TRAVELLING CABLES ON PIPE CAT. -REMOVE SHIMS FROM LOWER TORQUE TUBE CROSSMEMBER. 03:00 - 04:30 1.50 RIGU P PRE I INSTALL MOUSEHOLE LOAD E-LINE EQUIPMENT TO RIG FLOOR. PERFORM BLOCK HEIGHT CALIBRATION WITH SLB MWD. 04:30 - 05:00 0.50 BOPSUR P PRE PERFORM ACCUMULATOR UNIT DRAWDOWN TEST SEE ATTACHED AOGCC DOCUMENTATION FORM. 05:00 - 08:00 3.00 RIGU P PRE MAKEUP AND RUN IN HOLE WITH 12-1/4" DRILLING ASSEMBLY(WELL BHA#1). TAG AT 55'IN CONDUCTOR. -USED HUGHES 12-1/4"VM-3 MILL TOOTH -SLB POWERPAK 1.5°BENT HOUSING MOTOR WITH NON-PORTED FLOAT. 08:00 - 08:30 0.50 RIGU P PRE CLEANOUT CONDUCTOR FROM 55'MD TO 109'MD. -445 GPM,320 PSI,40 RPM -ICE IN RETURNS AT SHAKERS 08:30 - 09:00 0.50 RIGU P PRE RU HALLIBURTON E-LINE AND LOAD GYRODATA TOOLS TO RIG FLOOR. LOAD GYRO TOOLS TO RIG FLOOR 09:00 - 09:30 0.50 RIGU P PRE CLEANOUT CONDUCTOR FROM 109'MD TO 128'MD. -445 GPM,320 PSI,40 RPM 09:30 - 12:30 3.00 DRILL P SURF SPUD Z-114 WITH PARKER 273 AT 09:30 ON 7/7/2013. DRILL 12-1/4"SURFACE HOLE FROM 128'MD TO 418'MD. -450 GPM, 600 PSI ON,500 PSI OFF,40 RPM, 1-2KFT-LBS TORQUE ON,1 KFT-LBS TORQUE OFF -GYRO SURVEY EVERY STAND -ART=2.25 HRS,AST=0 HRS -WIPE HOLE 30 FT PRIOR TO CONNECTIONS, FULL PUMP RATE UP,PUMPS OFF DOWN -MW IN/OUT=8.7/8.8 PPG -LARGE AMOUNTS OF GRAVEL IN RETURNS AT SHAKERS. 12:30 - 13:30 1.00 DRILL P SURF PUMP OUT OF HOLE WITH 12-1/4"DRILLING ASSEMBLY FROM 416'MD TO SURFACE (UNABLE TO PULL OF ELEVATORS). -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) -PU WEIGHT OFF BOTTOM=58 KLBS,SO 58 KLBS 13:30 - 17:30 4.00 DRILL P SURF CHECK BIT(GRADE 1-1-IN GAUGE). MAKEUP LWD AND MWD TOOLS AND RUN IN HOLE (WELL BHA#2)TO PREVIOUSLY DRILLED TO DEPTH OF 416'MD. TAG 60'HIGH(FILL). WASH AND REAM DOWN. -WOOD IN RETURNS WHILE WASHING BACK TO BOTTOM. Printed 8/5/2013 1:41:31 PM • North America-ALASKA-BP Page 4 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 'X3-013F4-C:DRILL(5,680,681.18) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:OOAM Rig Release:7/24/2013 Rig Contractor.PARKER DRILLING CO. UVI: Active datum:Z-114 ACTUAL(§102.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 21:30 4.00 DRILL P SURF DRILL 12-1/4"SURFACE HOLE FROM 416'MD TO 758'MD. -500 GPM, 1100 PSI ON,950 PSI OFF,40 RPM,2-4KFT-LBS TORQUE ON,1KFT-LBS TORQUE OFF -GYRO SURVEY EVERY STAND UNTIL SECOND CLEAN MWD SURVEY RECORDED AT 758'BIT MD. RDMO HALLIBURTON E-LINE -WIPE HOLE 30 FT PRIOR TO CONNECTIONS, FULL PUMP RATE UP,PUMPS OFF DOWN -MW IN/OUT=8.8/8.8 PPG -LARGE AMOUNT OF GRAVEL SUBSIDES AT -650'. CLAY AND GRAVEL IN RETURNS. 21:30 - 00:00 2.50 DRILL P ` SURF DRILL 12-1/4"SURFACE HOLE FROM 758'MD TO 942'MD. -500 GPM, 1100 PSI ON,950 PSI OFF,40 RPM,2-4KFT-LBS TORQUE ON,1KFT-LBS TORQUE OFF -MWD SURVEY EVERY STAND -WIPE HOLE 30 FT PRIOR TO CONNECTIONS, FULL PUMP RATE UP,PUMPS OFF DOWN -MW IN/OUT=8.8/8.8 PPG,LSYP=50 -OBSERVE 12'FILL ON ONE CONNECTION AT 942'MD. WASH/REAM BACK TO BOTTOM. 7!8/2013 00:00 09:30 9.50 DRILL P SURF DRILL 12-1/4"SURFACE HOLE FROM 942'MD AT MIDNIGHT TO 1700'MD(80'MD ABOVE BASE OF PERMAFROST),758'IN 9.5 HOURS= 80 FPH WITH CONNECTIONS. -500 GPM,1150 PSI ON,1050 PSI OFF,60 RPM,2-5KFT-LBS TORQUE ON,1 KFT-LBS TORQUE OFF -INSTANTANEOUS ROP: ROTATING=125-175 FPH,SLIDING=50-100 FPH -MWD SURVEY EVERY STAND -WIPE HOLE 30 FT PRIOR TO CONNECTIONS, FULL PUMP RATE UP,PUMPS OFF DOWN -MW IN/OUT=8.8/8.8 PPG,LSYP=50 -ADT=6.42 HRS,ART=3.90 HRS,AST=2.52 HRS -SIMOPS: VISUALLY INSPECT BOP ELEMENTS FOR HIGH GOR SOP. ELECT TO REBUILD UPPER VARIABLE BORE RAMS. 09:30 - 11:00 1.50 DRILL P SURF PERFORM PLANNED WIPER TRIP. BACKREAM OUT OF HOLE AT 200 FPH,FROM 1700'MD TO 1400'MD WHILE CIRCULATING (3)BOTTOMS UP. -508 GPM,1270 PSI,60 RPM,3-4 KFT-LBS TORQUE,80K ROTATING WEIGHT -MONITOR WELL PRIOR TO PULLING OFF BOTTOM(STATIC) 11:00 - 12:30 1.50 DRILL , P SURF POOH WITH 12-1/4"DRILLING ASSEMBLY ON ELEVATORS FROM 1400'MD TO BHA AT 390' MD. INITIAL PICKUP WEIGHT=92 KLBS -MINOR TIGHT SPOTS ENCOUNTERED AT 670'-630'MD AND 1250'-1210'MD. 12:30 - 13:00 0.50 DRILL P SURF SERVICE RIG 13:00 - 17:00 4.00 DRILL N RREP 1,700.00 SURF IADC CODE 8 NPT: CHANGEOUT SAVER SUB. SHIM TORQUE TUBE TO CENTER TOP DRIVE OVER WELL. Printed 8/5/2013 1:41:31PM North America-ALASKA-BP Page 5 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL(102.05usft(above Mean Sea Level) Date From-To Mrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 18:30 1.50 DRILL P SURF RIH WITH 12-1/4"DRILLING ASSEMBLY ON ELEVATORS FROM BHA AT 390'MD TO 1700' MD -MINOR TIGHT SPOTS ENCOUNTERED AT 1200'MD-1300'MD 18:30 - 00:00 5.50 DRILL P SURF DRILL 12-1/4"SURFACE HOLE FROM 1700'MD TO 2309'MD AT MIDNIGHT(609'IN 5.5 HRS= 111 FPH WITH CONNECTIONS) -500 GPM,1400-1600 PSI ON,1250-1350 PSI OFF,60 RPM,171 BIT RPM,4-6 KFT-LBS TORQUE ON,2-3 KFT-LBS TORQUE OFF, 15-20 KLBS WOB -INSTANTANEOUS ROP: ROTATING=220-260 FPH,SLIDING=75-125 FPH -MWD SURVEY EVERY STAND -WIPE HOLE 30 FT PRIOR TO EVERY OTHER CONNECTION,FULL PUMP RATE UP,PUMPS OFF DOWN -MW IN/OUT=8.8/8.8 PPG,LSYP=53 -NO LOSSES TO FORMATION -PICKUP WEIGHT=100 KLBS,SO=94 KLBS, ROTATING=92 KLBS -ADT=3.68 HRS,ART=2.14 HRS,AST=1.54 HRS(TOTAL BIT HOURS=15.17) -SIMOPS: MAKEUP STANDS 4"DRILLPIPE 'WITH OFFLINE STAND BUILDING EQUIPMENT. 7/9/2013 00:00 - 11:00 11.00 DRILL P ' SURF DRILL 12-1/4"SURFACE HOLE FROM 2309'MD TO 3195'MD -500 GPM,1650-1750 PSI ON,1600 PSI OFF, 60 RPM,171 BIT RPM,4-6 KFT-LBS TORQUE ON,2.5-3 KFT-LBS TORQUE OFF -ROTATING=200-250,SLIDING=75-125 -MWD SURVEY EVERY STAND -WIPE HOLE 30 FT PRIOR TO EVERY OTHER CONNECTION,FULL PUMP RATE UP,PUMPS OFF DOWN MW IN/OUT=8.9/8.9 PPG,LSYP=53 -HYDRATES ENCOUNTERED AT 2465'-2490' MD. DEPTH CORRELATES TO FIRST BOTTOMS UP AFTER ENTERING SV3 AT 2388' MD. ABLE TO DRILL THROUGH AT FULL RATE. FLOW CHECK AFTER(STABLE). -NO LOSSES TO FORMATION 11:00 - 16:00 5.00 DRILL P SURF CBU X 2,BACKREAM OUT OF HOLE FROM 3195'MD TO 2875'MD ATTEMPT TO PULL ON ELEVATORS FROM 2,875-2820',SWABBING, PULL 50K OVER AND LOOSING DOWN WEIGHT 1 BACK REAM F2875'MD TO 2,480'MD 120 SPM ,600 GPM W/1600 PSI,50 RPM WITH 3 TO 5 K TQ,UP/WT 95K,DN/WT 90K,ROT 90K 'ATTEMPT TO PULL ON ELEVATORS FROM 2,480-2440',SWABBING, PULL 30K OVER BACKREAM FROM 2440 TO 1780 WITH DRILLING PARAMETERS ATTEMPT TO PULL ON ELEVATORS FROM 1,780-1740',SWABBING, PULL 20K OVER BACKREAM FROM 1780 TO 1600 16:00 - 16:30 0.50 DRILL P SURF PULL 2 STANDS FROM 1600 TO 1410 ON ELEVATORS,HOLE TAKING FLUID AND NO OVERPULL Printed 8/5/2013 1:41:31 PM North America-ALASKA-BP Page 6 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 18:00 1.50 DRILL P SURF TIH ON HOOK F/1417 MD TO 3125'MD 18:00 - 20:30 2.50 DRILL P SURF FILL PIPE AND WASH TO BOTTOM,NO FILL, CBU X 3 WHILE BACK REAMING F/3195'MD TO 2925'MD 20:30 - 22:30 2.00 DRILL P SURF POH ON HOOK AT45 TO 50 FPM UP TO 952' MD TO BHA. 22:30 - 00:00 1.50 DRILL P SURF MONITOR WELL FOR 10 MIN=STATIC,POH F/ 952 TO 202'MD 7/10/2013 00:00 - 03:00 3.00 DRILL P SURF LAY/DN 12-1/4 BHA. 03:00 - 04:00 1.00 CASING P SURF CLEAN AND CLEAR RIG FLOOR OF BHA TOOLS 04:00 - 07:00 3.00 CASING P SURF PU CASING RUNNING EQUIPMENT. RU VOLANT TOOL AND CASING RUNNING EQUIPMENT 07:00 - 07:30 0.50 CASING P SURF M/U LANDING JOINT AND DUMMY RUN TO MARK,M/U SHOE TRACK 07:30 - 12:00 4.50 CASING P SURF RUN 9-5/8",40#,L-80, BTC SURFACE CASING FROM SURFACE TO 651'MD WITH VOLANT TOOL. -CHECK FLOATS(PASS) -RUN(1)CENTRALIZER LOCKED DOWN 5' FROM SHOE,(1)CENTRALIZER LOCKED DOWN MID JOINT#2,(1)FREE FLOATING CENTRALIZER ON JOINT#3. -TORQUE BTC CONNECTIONS TO 10000 FT-KLBS. 12:00 - 17:00 5.00 CASING P SURF RUN 9-5/8",40#,L-80, BTC SURFACE CASING FROM 651'MD 2100'MD WITH VOLANT TOOL (AVERAGE 9 JTS/HR WHEN RUNNING) -FREE FLOATING CENTRALIZERS ON JOINT #4-25 -USE BEST-O-LIFE 2000 PIPE DOPE. -TORQUE CONNECTIONS TO 10000 FT-KLBS -RUN IN HOLE AT 10-20 FPM. FILL CASING EVERY JOINT,BREAK CIRCULATION EVERY 10TH JOINT(AVERAGE 6 BBLS LOS TO FORMATION). -MW IN/OUT=9.1 PPG -NO HOLE ISSUES ENCOUNTERED WHILE RUNNING PIPE 17:00 - 21:30 4.50 CASING P SURF RUN 9-5/8",40#,L-80, BTC SURFACE CASING FROM 651'MD PLANNED CASING SETTING DEPTH OF 3187'MD(8'OFF BOTTOM) WITH VOLANT TOOL(AVERAGE 9 JTS/HR WHEN RUNNING) -USE BEST-O-LIFE 2000 PIPE DOPE. -TORQUE CONNECTIONS TO 10000 FT-KLBS -RUN IN HOLE AT 10-20 FPM. FILL CASING EVERY JOINT,BREAK CIRCULATION EVERY 5TH JOINT.(NO LOSSES TO FORMATION) -CIRCULATE 15 MIN AT 8 BPM AT JT#60. IMPROVE DRAG TREND -NO HOLE ISSUES ENCOUNTERED WHILE RUNNING -FINAL PU WEIGHT=160K,SO=140K -MU HANGER AND LANDING JT.LAND ON RING AT SAME DEPTH AS DUMMY RUN. Printed 8/5/2013 1:41:31 PM • North America-ALASKA-BP Page 7 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/1B/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:OOAM Rig Release:7/24/2013 Rig Contractor PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 00:00 2.50 CASING P SURF CIRCULATE HOLE CLEAN AND CONDITION MUD FOR CEMENTING. -CIRCULATE INITIALLY AT 3 BPM,THEN STAGE UP PUMPS FROM 3 BPM TO 8 BPM THROUGH TOP DRIVE IN 1 BBL INCREMENTS. INITIAL CIRC PRESSURE AT 8 BPM=780 PSI. -RECIPROCATE PIPE IN 10'-20'STROKES WHILE CIRCULATING.FINAL PU WEIGHT= 150 KLBS,SO=140 KLBS -CUT MUD YIELD POINT BACK FROM 70 TO 15-20 LB/100FT^2 -MIRU SCHLUMBERGER CEMENTERS AND STAGE SUPPORT TRUCKS,BATCH UP 100 BBLS 10 PPG MUD PUSH SPACER 7/11/2013 00:00 - 00:30 0.50 CASING P SURF CIRC WELL 80 SPM @ 650 PSI,RECIPRICATE PIPE 20',UP WT=150,DN WT 140 AND RIG UP CEMENTERS 00:30 - 05:30 5.00 CASING P SURF PJSM W/ALL RIG PERSONAL CEMENT 9 5/8"SURFACE CASING AS FOLLOWS: -FILL LINES WITH WATER AND PRESSURE TEST TO 3500 PSI FOR 5 MINUTES PUMP 100 BBLS OF 10.0 PPG MUDPUSH II SPACER @ 5.0 BPM,120 PSI -RELEASE BOTTOM PLUG -PUMP 598 BBLS OF 11.0 PPG LITECRETE LEAD CEMENT @ 5.0 BPM,EXCESS VOLUME 450%SURFACE TO BPERM, 40%BPERM TO TAIL SLURRY(YIELD 1.91 CU.FT/SK) -PUMP 70 BBLS OF 15.8 PPG CLASS G TAIL @ 5.0 BPM,EXCESS VOLUME 40% (YIELD 1.16 CU.FT/SK) -DROP TOP PLUG -RECIPROCATED PIPE 20 FT AT SURFACE WHILE PUMPING CEMENT AT 5.0 BPM PERFORM DISPLACEMENT WITH RIG PUMPS AND 9.1 PPG DRILPLEX MUD PER SLB CADE -139 BBLS DISPLACED AT 10 BPM:ICP 40 PSI 100%RETURN FLOW,FCP 350 PSI 100% RETURN FLOW -80 BBLS DISPLACED AT 7 BPM:ICP 305 PSI 100%RETURN FLOW,FCP 820 PSI 100% RETURN FLOW -REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 922 PSI -BUMP PLUG AND INCREASE PRESSURE TO 1223 PSI,CHECK FLOATS-GOOD -TOTAL DISPLACEMENT VOLUME 223 BBLS (MEASURED BY STROKES @ 96%PUMP EFFICIENCY) -RECIPROCATE PIPE 20 FT AT SURFACE DURING DISPLACEMENT, RECIPROCATION STOPPED WHEN HALF OF LEAD CMT WAS PUMPED. -400 BLS OF CEMENT RETURNS TO SURFACE -TOTAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE:0 BBLS Printed 8/5/2013 1:41:31 PM North America-ALASKA-BP Page 8 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) I Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad _ - Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date j From-To Hrs Task Code 1 NPT I NPT Depth I Phase Description of Operations (hr) (usft) 05:30 - 09:00 3.50 CASING P SURFWASH UP STACK AND JET FLOW LINE. I,FUNCTION ANNULAR,BACK OUT LANDING JT, 'CHANGE OUT ELEVATOR LINKS AND LAY DN VOLANT TOOL 09:00 - 17:00 8.00 CASING P SURF PJSM,NIPPLE DOWN DIVERTER STACK __ I SPOOLS AND DIVERTER LINES 17:00 - 19:00 2.00 CASING P SURF PJSM,NIPPLE UP 11"FMC WELL HEAD AND TEST 19:00 - 00:00 5.00 CASING .. P ! SURF NIPPLE UP BOP AND RISER SPOOLS j 7/12/2013 00:00 - 03:30 3.50 CASING P SURF NIPPLE UP BOP 03:30 - 06:00 2.50 CASING P SURF RIG UP TEST EQUIPMENT.SET TEST PLUG. I _____ 06:00 - 07:00 1.00 CASING P SURF W LD 4"HDP STANDS OFF-LINE 07:00 - 13:30 6.50 CASING P SURF PRESSURE-FUNCTION TEST BOPE TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN I EACH WITH 4"TEST JOINT PER ADWOP !STANDARDS AND AOGCC REGULATIONS. ' I TEST WITNESSED BY LOU GRIMALDI,AOGCC REPRESENTATIVE. -ALL BOPE TEST CHARTS AND REPORT ARE ATTACHED. -(2)HT38 FOSV,(1)4-1/2"IF FOSV,&(1)4" HT38 DART VALVE TESTED. -CLOSURE TIMES FOR BOP COMPONENTS ALL MEASURED -ALL PASSING TESTS 13:30 - 14:30 1.00 CASING P SURF RIG DOWN BOPE TEST EQUIPMENT. REMOVE TEST PLUG AND INSTALL 9-7/8" WEAR RING. MU SHEARABLE SAFETY JT. 14:30 - 16:00 1.50 CASING P SURF RU TO TEST 9-5/8"CASING.FILLALL LINES AND PURGE AIR. F CLOSE BLIND RAMS AND PRESSURE TEST 13-3/8"SURFACE CASING AGAINST OUTER WORKING ANNULUS VALVES TO 250 PSI LOW FOR FIVE MIN AND 3500 PIS HIGH FOR 30 MIN (PASSING TESTS,SEE ATTACHED DOCUMENTATION). 16:00 - 20:00 4.00 CASING P SURF PU AND MU 8-3/4"DRILLING BHA. 20:00 - 22:00 2.00 CASING P SURF RIH ON ELEVATORS WITH 8-3/4"DRILLING BHA TO 960'MD. PERFORM SHALLOW HOLE TEST FOR LWD TOOLS AT 960'MD;460 GPM,1300 PSI. RIH FROM 960'MD TO 2850'MD 22:00 00:00 2.00 CASING P j SURF ,M/U TD AND FILL PIPE,UP WT=120K,DN Wr=115K WASH DN F/2858'MD TO 3103 AND TAG FLOAT COLLAR.'MD,130 SPM/550 GPM, WITH 2300 PSI,20 RPM,3-5K TQ,KICK WHILE TRIPPING D-1 DRILL CRT-2 MIN 25 SEC 7/13/2013 00:00 - 02:00 2.00 CASING P SURF 'DRILL SHOE TRACK F/3103'MD TO 3170'MD, START DISPLACEMENT W/NEW 9.2 LSND MUD,130 SPM @ 2300 PSI,30 RPM,TAG 1 SHOE @ 3184'MD,CONT TO DRILL TO 3210 DISPLACEMENT COMPLETE,PULL BACK UP INTO CASING SHOE©3182'MD 02:00 - 02:30 0.50 CASING P SURF !RIG UP AND PERFORM LOT '-MUD WEIGHT:9.2 PPG,3184'TVD,3187'MD -PUMP 2.9 BBLS TO 1320 PSI,BLEED BACK 2.1 BBLS LOT EMW=15.24 PPG Printed 8/5/2013 1.41:31PM • North America-ALASKA-BP Page 9 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 03:00 0.50 DRILL P PROD1 CIRC AND WAIT ON LOT APPROVAL 03:00 - 06:00 3.00 DRILL P PROD1 DRILL 8.75°PRODUCTION HOLE FROM 3208' MD TO 3325'MD(3318'TVD) -600GPM, 1800 PSI ON,1750 PSI OFF -41 RPM,2-3K TORQUE ON,2-3K TORQUE OFF -PU 120K,SO 110K,ROT 115K ,-SURVEY EVERY-90 FT -BACKREAM 30 FT PRIOR TO CONNECTIONS -MUD WEIGHT:9.2 PPG IN,9.2 PPG OUT 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 3325'MD TO 4191'MD(4043 TVD) -600GPM, 2360 PSI ON,2100 PSI OFF -80 RPM,6K TORQUE ON,5K TORQUE OFF PU 131K,SO 118K,ROT 121K -SURVEY EVERY-90 FT -BACKREAM 30 FT PRIOR TO CONNECTIONS -MUD WEIGHT:9.2 PPG IN,9.2 PPG OUT 12:00 - 00:00 12.00 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 4191'MD TO 5805'MD(4684'TVD) -600GPM, 2700 PSI ON,2600 PSI OFF -80 RPM,8K TORQUE ON,4K TORQUE OFF -PU 131 K,SO 110K,ROT 115K SURVEY EVERY-90 FT -BACKREAM 90 FT PRIOR TO CONNECTIONS -MUD WEIGHT:9.2 PPG IN,9.2 PPG OUT 7/14/2013 00:00 - 12:00 12.00 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 5805'MD TO 7036'MD(5161'TVD) -600GPM, 2700 PSI ON,2600 PSI OFF -80 RPM,8K TORQUE ON,4K TORQUE OFF -PU 131 K,SO 110K,ROT 115K -SURVEY EVERY-90 FT -BACKREAM 90 FT PRIOR TO CONNECTIONS -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT 12:00 - 00:00 12.00 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 7036'MD TO 8366'MD(5666'TVD) -600GPM, 3580 PSI ON,3480 PSI OFF -100 RPM,9K TORQUE ON,5K TORQUE OFF -PU 165K,SO 115K,ROT 124K -SURVEY EVERY-90 FT -BACKREAM 90 FT PRIOR TO CONNECTIONS -MUD WEIGHT:9.6 PPG IN,9.6 PPG OUT -ECD=10.5 PPG SIMOPS: -MU 10 STANDS WITH OFF LINE STAND BUILDER 7/15/2013 00:00 - 01:00 1.00 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 8366'MD TO 8500'MD(5700'ND) -600GPM, 3580 PSI ON,3480 PSI OFF -100 RPM,9K TORQUE ON,5K TORQUE OFF -PU 165K,SO 115K,ROT 124K -SURVEY EVERY-90 FT -BACKREAM 90 FT PRIOR TO CONNECTIONS -MUD WEIGHT:9.9 PPG IN,10.PPG OUT -ECD=10.5 PPG 01:00 - 02:30 1.50 DRILL P PROD1 CIRC TO WT UP MUD SYSTEM TO 10.4 Printed 8/5/2013 1:41:31 PM North America-ALASKA-BP Page 10 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.O5usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 10:30 8.00 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 8500'MD TO 9000'MD(5921'TVD) -565GPM, 3 PSI ON,3480 PSI OFF -100 RPM,9K TORQUE ON,5K TORQUE OFF -PU 166K,SO 116K,ROT 128K -SURVEY EVERY-90 FT -BACKREAM 90 FT PRIOR TO CONNECTIONS -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -ECD=11.2 PPG LOST RETURNS AT 8800'MD.FLOW CHECK WELL. -AT 450GPM LOSS RATE OF 30BPH -AT 55OGPM LOSS RATE OF 60BPH. 1_ADD LCM AT 4SACKS/HR NO LOSSES AT 9000'MD. -FLOW CHECK AFTER EACH STAND 10:30 - 12:00 1.50 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 9000'MD TO 9125'MD(5983'TVD) -550GPM, 3940 PSI ON,3700 PSI OFF -100 RPM,10K TORQUE ON,6-7K TORQUE OFF -PU 174K,SO 115K,ROT 130K SURVEY EVERY-90 FT BACKREAM 90 FT PRIOR TO CONNECTIONS -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -ECD=11.2 PPG NORMAL LOSSES TO DRILLING 12:00 - 00:00 12.00 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 9125'MD TO 9810'MD(6554'TVD) -525GPM, 3900 PSI ON,3770 PSI OFF -80 RPM,10K TORQUE ON,7K TORQUE OFF -PU 187K,SO 121K,ROT 134K -SURVEY EVERY-90 FT -BACKREAM 90 FT PRIOR TO CONNECTIONS -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT ECD=11.5 PPG NORMAL LOSSES TO DRILLING 7/16/2013 00:00 - 00:30 0.50 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 9810'MD TO 9867'MD(6478'TVD) -520GPM, 3980 PSI ON -80 RPM,10K TORQUE ON -PU 198K,SO 125K,ROT 143K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -ECD=11.2 PPG NORMAL LOSSES TO DRILLING 00:30 - 07:00 6.50 DRILL N DPRB 9,867.00 PROD1 DRILLER REPORTED PIT GAIN,(8 TO 10BLS) / STOPPED TO FLOW CHECK WELL,VERIFIED FLOW,SHUT IN WELL.MADE LEVEL 0 NOTIFICATION AND BEGAN CIRCULATING OUT KICK USING DRILLERS METHOD.SIDP 118,SICP 64,AFTER 30MIN PSI DROPPED ON BOTH SIDP 35 AND SICP 20 07:00 - 10:30 3.50 DRILL N DPRB 9,867.00 PROD1 ATTEMPT EXHALE TEST-BLEED OF TO TRIP TANK,2.2 BLS RETURNED,PUMP 500 STKS, 37 SPM @ 850 PSI,SHUT DN BLEED BACK 1.5 BLS TO TRIP TANK,RECIPROCATE PIPE 20' DP=O CSG=0,UP WT 208,DNWT 118, MONITOR WELL 10 MIN=STATIC Printed 8/5/2013 1:41:31 PM • North America-ALASKA-BP Page 11 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 12:00 1.50 DRILL N DPRB 9,867.00 PROD1 OPEN ANNULAR AND CIRC BOTTOMS UP AT DRLG RATE,120 SPM @ 3720 PSI,525 GPM, MONITOR WELL FOR 10 MIN=OBSERVE SMALL AMOUNT OF FLOW,LOST 15 BLS 12:00 - 15:00 3.00 DRILL N DPRB 9,867.00 PROD1 PREFORM EXHALE TEST TO DETERMINE WELLBORE STABILITY 1 BL=7 MIN "2BL=8 MIN 3BL=13 MIN 4BL=46 MIN 15:00 - 22:30 7.50 DRILL P PROD1 DIRECTIONAL DRILL 8.75"PRODUCTION HOLE FROM 9867'MD TO TD 10245'MD(6872' TVD) -525GPM, 4150 PSI ON,3840 PSI OFF 80 RPM,12K TORQUE ON,10K TQ OFF -PU 221K,SO 125K,ROT 152K -MUD WEIGHT:10.4+PPG IN,10.5 PPG OUT ECD='11.7 PPG 22:30 - 23:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS-UP 1 TIMES -525 GPM,3800 PSI -80 RPM,10K TORQUE -RECIPROCATE PIPE AT 10 FT/MIN SLOWLY PULLED 1 STAND WHILE CBU. -PUMP HIGH VIS SWEEP,DID NOT CHANGE CUTTINGS ON RETURN. 23:30 - 00:00 0.50 DRILL P PROD1 1 RIG SERVICE 7/17/2013 00:00 - 02:00 2.00 DRILL P PROD1 BACKREAM MAD PASS F/10160'MD TO 9826' MD 02:00 - 12:00 10.00 DRILL P PROD1 BACK REAM OUT OF HOLE FROM 9828'MD TO 7606'MD -525 GPM,3450 PSI AT 9826'MD -100 RPM,8K TORQUE,141K ROTATING WEIGHT -BACKREAMING SPEEDS FROM 8 FT/HR-12 FT/HR -TIGHT HOLE @ 8939 WITH 100 BLS FLUID LOSSES,ECD 12.4 -FINGER PRINT FLOW RETURNS AFTER PUMP IS DOWN 12:00 - 15:00 3.00 DRILL P PROD1 BACK REAM OUT OF HOLE FROM 7606'MD TO 6563'MD -550 GPM,3250 PSI AT 7606'MD,ECD 11.2 -100 RPM,8K TORQUE,141K ROTATING WEIGHT -BACKREAMING SPEEDS FROM 8 FT/HR-12 FT/HR -FINGER PRINT FLOW RETURNS AFTER , PUMP IS DOWN 15:00 - 16:00 1.00 DRILL P PROD1 CBU FROM 6563 WHILE PULLING 2 STDS SLOW 16:00 - 16:30 0.50 DRILL P PROD1 IFLOW CHECK WELL 15 MIN=STATIC,1/4 BBLS — _ — RETURN WHEN PUMPS SHUT DOWN. 16:30 - 18:00 1.50 DRILL P PROD1 TIH ON HOOK F/6563'MD TO 8808'MD 18:00 - 19:00 1.00 DRILL P PROD1 TIGHT SPOT @ 8908'MD,ATTEMPT TO WIPE 4X,ORIENT TOOL TO LOW SIDE AND ATTEMPT TO WIPE(NO-GO),STAGE UP PUMPS TO 20 SPM WORK 2 X,INCREASE RATE TO 94 SPM AND WORK PAST TIGHT SPOT,REAM OUT TIGHT SPORT 2 X IN UPWARD MOVEMENT. Printed 8/5/2013 1:41:31 PM North America-ALASKA-BP Page 12 of 12 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:DRL-ONSHORE(DON) Start Date:7/2/2013 End Date:7/18/2013 X3-013F4-C:DRILL(5,680,681.19) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL©102.05usft(above Mean Sea Level) Date I From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 119:00 - 21:00 2.00 DRILL P PROD1 TIH ON HOOK F/8908'MD TO 10245'MD 21:00 - 00:00 3.00 DRILL P PROD1 CIRCULATE BOTTOMS-UP 4 TIMES -540 GPM,3930 PSI -100 RPM,8-10K TORQUE -RECIPROCATE PIPE AT 20 FT/MIN -PUMP 30 BLS HIGH VIS SWEEP AFTER 1ST BOTTOMS UP 7/18/2013 100:00 - 00:30 0.50 DRILL P PROD1 SPR ON PUMPS,FLOW CHECK WELL 15MIN=STATIC f 100:30 - 06:30 6.00 DRILL P PROD1 POH ON HOOK 20 FPM UP TO 8800 FT, 1 I INCREASE SPEED TO 40 FPM,PUMP DRY JOB @ 7600'MD MONITOR WELL BY TRIP TANK,WELL TAKING CORRECTAMOUNT PER 5 STDS 2.7 BLS 06:30 - 07:00 0.50 DRILL N HMAN '5,700.00 PROD1 SAFETY STAND DOWN DUE TO FLOOR INCIDENT,DERRICK HAND INJURED FINGER, 07:00 - 10:00 3.00 DRILL P PROD1 POH TO CASING SHOE,FLOW CHECK WELL 15MIN=STATIC 10:00 - 11:00 1.00 DRILL N HMAN 3,187.00 PROD1 SAFETY STAND DOWN AND RE-ENACTMENT OF INCIDENT,ENTERED IN TRACTION REPORT#IR-4476325 11:00 - 12:30 1.50 DRILL P j -PROD1 PQH FROM CASING SHOE 3186'MD TO 920' MD 12:30 - 13:00 0.50 DRILL P i PROD1 MONITOR WELL=STATIC,CHANGE OUT MASTER BUSHING FOR PS-21 13:00 - 14:00 1 1.00 DRILL P I PROD1 LID 9-4"HWDP/SINGLES,9-5"HWDP/SINGLES, JARS 14:00 - 14:30 0.50 DRILL N HMAN`'- 218.00 PROD1 SAFETY STAND DOWN FOR ACCIDENT 'INVESTIGATION 14:30 - 16:30 2.00 DRILL P PROD1 L/D BHA TOOLS AND BIT i 16:30 - 22:30 6.00 DRILL P PROD1 CLEAR RIG FLOOR,DRAIN STACK BELOW RAMS,CLOSE BLIND RAMS AND CIRC THROUGH CHOKE TO MONITOR WELL, CHANGE OUT TOP RAMS TO 7"CASING RAMS,DRAIN STACK TO PULL WEAR BUSHING.RIG UP TEST JOINT AND TEST I i RAMS AND ANNULAR 250 LOW/5MIN,4000 HIGH/5 MIN,RIG DOWN TEST JOINT 22:30 - 00:00 1.50 DRILL P I PROD1 RIG UP TO RUN 7"CASING VOLANT TOOL. Printed 8/5/2013 1:41:31PM North America-ALASKA-BP Page 1 of 5 Operation Summary Report Common Well Name Z-114 AFE No Event Type COM-ONSHORE(CON) ' Start Date 7/19/2013 End Date:7/24/2013 X3-013F4-C DRILL(3,573,686.00) Project:Prudhoe Bay Site:PBZ Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM .Rig Release:7/24/2013 Rig Contractor PARKER DRILLING CO. UVVI: Active datum Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs Task 1 Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 7/19/2013 00:00 - 03:00 3.00 CASINGP I RUNPRD RIG UP TO RUN 7"26#CASING,M/U LANDING JOINT AND HANGER AND MAKE DUMMY RUN, MARK WELL#AND DATE ON LANDING JOINT. 03:00 - 04:00 1.00 CASING N RREP 41.00 RUNPRD IADC CODE B NPT: REPAIR P-21 SLIPS,PULL PS-21 SLIPS AND INSTALL MASTER BUSHING. 04:00 - 15:00 11.00 CASING P RUNPRD RUN 7"26#L-80 CASING FROM SURFACE TO ,3151'MD. 15:00 - 16:00 1.00 CASING P RUNPRD CIRC CASING 2.6X BUS,STAGE UP PUMPS TO 7 BPM @ 649 PSI,BBLAN=BBLJOUT 16:00 - 21:00 5.00 CASING P RUNPRD RUN 726#L-80 CASING FROM 3151'MD TO 5289'MD.CIRC EVERY 5 JTS 21:00 - 22:30 1.50 CASING P ' RUNPRD CIRC CASING 1X BUS,CHANGE OUT JOINT r 129 WITH SPARE,CHANGE OUT CABLE ON POWER TONGS 22:30 - 00:00 1.50 CASING P RUNPRD RUN 7"26#L-80 CASING FROM 5289'MD TO 6604'MD.CIRC EVERY 10 JTS 7/20/2013 00:00 - 07:00 7.00 CASING P RUNPRD RUN 726#L-80 CASING FROM 6604MD TO 9484'MD.CIRC EVERY 10 JTS,2 TO 5 BLS LOSSES PER 10 JTS 07:00 - 08:00 1.00 CASING P RUNPRD CIRC BOTTOMS UP©9484'MD,50SPM @ 665 PSI,2600 STKS,UP WT=225,DN WT 124 08:00 - 10:30 2.50 CASING P I I RUNPRD RUN 7"26#CASING FROM 9484'MD TO 10186' I MD,CIRC EVERY 10 JOINTS,CIRC LAST 2 JOINTS TO BOTTOM,40 SPM @ 610 PSI, P/U=245,S/O 128 1030 - 11:00 0.50 ' CASING P RUNPRD PICK UP HANGER AND LANDING JOINT @ 10235 11:00 - 16:30 5.50 CASING P RUNPRD CIRCULATE AND RECIPROCATE 15'STAGING UP PUMP RATE 2 BPM TO 5 BPM @ 740 PSI, P/U=265,S/0 120,BLOW/DN AND TEST ALL CEMENT LINES. Printed 8/5/2013 1 42 26PM North America-ALASKA-BP Page 2 of 5 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2013 End Date:7/24/2013 X3-013F4-C:DRILL(3,573,686.00) Project Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 16:30 - 20:30 4.00 CASING P RUNPRD CEMENT T PRODUCTION CASING AS FOLLOWS: -FILL LINES WITH WATER AND PRESSURE TEST TO 4000 PSI FOR 5 MINUTES -PUMP 45 BBLS OF 11.0 PPG MUDPUSH II SPACER @ 5 BPM,742 PSI -RELEASE BOTTOM PLUG PUMP 177.5 BBLS OF 11.5 PPG LITECRETE LEAD CEMENT @ 5 BPM,EXCESS VOLUME 30%(YIELD 1.76 CU.FT/SK) -PUMP 38 BBLS OF 15.8 PPG CLASS G TAIL© 5 BPM,EXCESS VOLUME 30% (YIELD 1.17 CU.FT/SK) -DROP TOP PLUG -RECIPROCATED PIPE 10 FT AT SURFACE ,WHILE PUMPING CEMENT AT 5 BPM PERFORM DISPLACEMENT WITH RIG PUMPS AND 9 PPG BRINE PER SLB CADE -224 BBLS DISPLACED AT 5 BPM:ICP 300 PSI 99%RETURN FLOW,FCP 561 PSI 99% RETURN FLOW -108 BBLS DISPLACED AT 3 BPM:ICP 584 PSI 99%RETURN FLOW,FCP 883 PSI 99% RETURN FLOW -REDUCE RATE TO 1 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 753 'PSI -BUMP PLUG AND INCREASE PRESSURE TO 1300 PSI,CHECK FLOATS-GOOD -TOTAL DISPLACEMENT VOLUME 384.6 BBLS (MEASURED BY STROKES @ 96%PUMP EFFICIENCY) -RECIPROCATE PIPE 10 FT AT SURFACE DURING DISPLACEMENT,300 BBLS PUMPED RECIPROCATION STOPPED. -TOTAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE:14 BBLS 20:30 - 22:00 1.50 CASING P RUNPRD PRESSURE TEST 7"CASING,250 LOW/5 MIN, 4000 HIGH/30 MIN 22:00 - 00:00 2.00 CASING P RUNPRD LAY/DN LANDING JOINT,DRAIN STACK AND WASH,R/D CASING TONGS,M/U PACK OFF RUNNING TOOL TO 7"PACK OFF,RIH&SEAT PACK OFF,VERIFY SEAT AND LOCK DN,LAY/ DN RUNNING TOOL. 7/21/2013 00:00 - 01:00 1.00 WHSUR P OTHCMP TEST 7"PACK OFF AS PER FMC REP,TEST 250 LOW FOR 5MIN,5000 HIGH FOR 30 MIN, RD VOLANT TOOL,LONG BAILS&BAIL EXTENTIONS,RIG UP SHORT BAILS AND BX ELEVATORS. 01:00 - 04:00 3.00 BOPSUR P OTHCMP R/U FOR INJECTIVITY TEST AND PUMP DN 0/A BROKE OVER @ 400 PSI,INJECT 10 BBLS @ 3 BPM 500 PSI,CHANGE OUT 7"CASING RAMS AND READY STACK FOR TEST. 04:00 - 06:00 2.00 BOPSUR P OTHCMP M/U 4.5"TEST JOINT AND TEST PLUG,TEST 2 7/8"X 5 1/2'RAMS,250 LOW 5/MIN,4000 HIGH 5/MIN CHART,UD TEST JOINT. 06:00 - 20:00 14.00 BOPSUR P OTHCMP WOC,PUMP ON 0/A,5SPM 220 PSI 3 BBLS AWAY EVERY 2 HRS,CHANGE OUT VALVE ON STANDPIPE MANIFOLD,LAY DN 4"DP OFF LINE,LOAD 4.5 TUBING IN PIPE SHED, Printed 8/5/2013 1:42:26PM North America-ALASKA-BP Page 3 of 5 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2013 End Date:7/24/2013 X3-013F4-C DRILL(3,573,686.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UVN: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs ' Task Code NPT NPT Depth j Phase Description of Operations (hr) (usft) 20:00 - 21:30 1.50 BOPSUR P OTHCMP SLIP AND CUT DRILL LINE,INJECT 100 BBLS OF 13.1 PPG MUD DOWN 0/A,2.5 BPM, I � ICP=440,FCP=300 PSI 21:30 - 22:00 0.50 BOPSUR P OTHCMP LOAD RIG FLOOR WITH E-LINE TOOLS. 22:00 - 00:00 2.00 BOPSUR P OTHCMP FREEZE PROTECT 9 5/8X7"PUMP 2 BPM, ICP=356,FCP=139,960 SHUT IN PSI ON O/A 7/22/2013 00:00 - 02:00 2.00 EVAL P OTHCMP RIG UP E-LINE,PICK UP AND MAKE UP TOOLS. 02:00 - 18:00 16.00 EVAL P OTHCMP TEST USIT TOOLS,RIH WITH TOOLS.USE SLB TRACTOR TO GET TO BOTTOM.LOG TO SURFACE.(PDF COPY OF LOG ATTACHED) SIMOPS,LAY DN 4"DP OFF LINE 18:00 - 21:00 3.00 EVAL P OTHCMP R/D E-LINE AND CLEAR FLOOR OF LOGGING TOOLS, 21:00 - 22:00 1.00 RUNCOM P RUNCMP R/U TO RUN 4.5 COMPLETION TUBING. 22:00 - 00:00 2.00 RUNCOM P RUNCMP PJSM,RUN 4.5 12.6#COMPLETION TUBING, 1 BAKER LOCK FIRST 3 CONNECTIONS 7/23/2013 00:00 - 12:00 12.00 RUNCOM P RUNCMP RUN IN HOLE WITH 4-1/2",12.6#,13CR-85, VAMTOP COMPLETION ASSEMBLY FROM 987' MD AT MIDNIGHT TO FINAL FULL JOINT#241 AT 9721'MD 12:00 - 13:30 1.50 RUNCOM P RUNCMP MAKEUP 11"X 4-1/2"FMC(TC-II LIFT THREADS,)MANDREL TUBING HANGER AND LANDING JOINT. RUN IN HOLE AND LAND AT 9791'MD -(241)FULL JOINTS,(3)GAS-LIFT MANDRELS, (1)PERMANENT HES 7"X 4-1/2"TNT PACKER, (1)'XN'NIPPLE,(3)'X'NIPPLES -DCK-2 SHEAR VALVE IN GLV#1 AT 9600'MD -FINAL PICKUP WEIGHT=114 KLBS, SLACKOFF=80 KLBS. 13:30 - 17:00 3.50 RUNCOM P RUNCMP RUN IN LOCKDOWN SCREWS ON TUBING HANGER. REVERSE CIRCULATE IN 330 BBLS CLEAN 10.4 PPG BRINE;4 BPM,600 PSI. -PUMP 5 BBLS 8.5 PPG SEAWATER DOWN TUBING TO CLEAN OFF RHC PLUG BODY 17:00 - 17:30 0.50 RUNCOM P RUNCMP MAKEUP LANDING JOINT AND DROP 1-7/8" BALL&ROD ON ROLLERS TO RHC PLUG IN XN NIPPLE AT 9259'MD. ALLOW B&R TO DROP FOR 15 MIN. LAYDOWN LANDING JOINT. 17:30 - 20:30 3.00 RUNCOM P RUNCMP SET HES TNT PACKER. PRESSURE TEST TUBING TO 250 PSI LOW FOR FIVE MIN AND .4000 PSI HIGH FOR 30 MIN(PASS). BLEED TUBING PRESSURE TO 2500 PSI AND MAINTAIN DURING IA TEST. PRESSURE TEST INNER ANNULUS TO 250 PSI LOW FOR FIVE MIN AND 4000 PSI HIGH FOR 30 MIN(PASS, SEE ATTACHED DOCUMENTATION FOR BOTH TESTS). BLEED OFF IA PRESSURE TO 0 PSI. BLEED OFF TUBING TO 0 PSI. OBTAIN APPROVAL TO PROCEED FROM WELLS TEAM LEADER. -VOLUMES PUMPED IN=VOLUMES BLED BACK(DOCUMENTED 1 HOUR MONITORING PERIOD FOR SETTING TWC) Printed 8/5/2013 1 42:26PM • • North America-ALASKA-BP Page 4 of 5 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2013 End Date:7/24/2013 'X3-013F4-C:DRILL(3,573,686.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:00AM Rig Release:7/24/2013 Rig Contractor.PARKER DRILLING CO. UW: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date i- From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 21:30 1.00 RUNCOM P RUNCMP PRESSURE UPON TUBING TO 2000 PSI. PRESSURE UP ON IA TO 3500 PSI. BLEED OFF TUBING QUICKLY TO SHEAR DCK 2 VALVE IN GLM#1 AT 9600'MD. PUMP DOWN TUBING TO VERIFY ABILITY TO CIRCULATE THROUGH GLV. -LINED UP ON IA: 3 BPM,1400 PSI -LINED UP ON TUBING: 3 BPM,1700 PSI 21:30 - 00:00 2.50 WHSUR P WHDTRE DRAIN BOP STACK,CLEANOUT FLOWBOX AND SET TWC WITH DRY ROD. MAKEUP LANDING JOINT AND PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOWAND 3500 PSI HIGH FOR 5 MIN EACH(PASSING TESTS,SEE ATTACHED CHART). -PRESSURE TESTING CONCLUDED ON 7/24/13 7/24/2013 00:00 - 01:00 1.00 ' WHSUR P WHDTRE PRESSURE TEST TWC FROM BELOW TO 250 PSI LOW AND 3500 PSI HIGH FOR 30 MIN I(PASSING TESTS,SEE ATTACHED CHARD. 01:00 - 02:00 1.00 WHSUR P WHDTRE I RIG DOWN TESTING EQUIPMENT. BLOWDOWN LINES. 02:00 - 08:00 6.00 BOPSUR P WHDTRE NIPPLE DOWN BELL NIPPLE,BOP STACK AND HIGH PRESSURE RISERS. SECURE BOP STACK ON STUMP FOR RIG MOVE. -SIMOPS: LOAD 9-5/8"SURFACE CASING INTO PIPE BARN FOR NEXT WELL Z-68, CLEAN PITS. BARRIERS TO NIPPLE DOWN: TUBING:TWC TESTED FROM BELOW,KWF ON TOP OF BALL AND ROD IN RHC-M PROFILE INNER ANNULUS: TESTED PRODUCTION PACKER,KWF AND CASING ANNULUS VALVES 08:00 - 14:00 6.00 WHSUR P WHDTRE NIPPLE UP FMC 4-1/16"5K TUBING HEAD ADAPTER AND 4-1/8"DRY HOLE TREE (DOUBLE MASTER VALVES). FMC REPRESENTATIVE PRESSURE TEST ADAPTER TO 250 PSI LOW FOR FIVE MIN AND 5000 PSI HIGH FOR 10 MIN. RIG CREW TEST DRY HOLE TREE WITH DIESEL TO 250 PSI LOWAND 5000 PSI HIGH FOR FIVE MIN EACH (ALL PASSING TESTS,SEE ATTACHED CHART). 14:00 16:00 2.00 WHSUR P WHDTRE MIRU VALVE SHOP LUBRICATOR CREW.RIG UP AND PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH TO LEAK-TIGHT CRITERIA(PASS,SEE ATTACHED CHART). PULL 4"CIWTYPE'H' TWC. RDMO LUBRICATOR CREW. Printed 8/5/2013 1:42:26PM North America-ALASKA-BP Page 5 of 5 Operation Summary Report Common Well Name:Z-114 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2013 End Date:7/24/2013 X3-013F4-C:DRILL(3,573,686.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/7/2013 9:30:OOAM Rig Release:7/24/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:Z-114 ACTUAL @102.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 20:30 4.50 WHSUR P WHDTRE MOVE IN LITTLE RED PUMP TRUCK AND PRESSURE TEST LINES TO 3000 PSI. REVERSE IN 17 BBLS 90°F 6.8 PPG DIESEL TO FREEZE PROTECT TUBING(8 BBLS)AND INNER ANNULUS(9 BBLS)TO 500'MD. ALLOW DIESEL TO U-TUBE FROM IA TO TUBING FOR ONE HOUR. FLOWCHECK AND PRESSURE CHECK WELL(STATIC). -2 BPM,700 PSI INITIAL WELLHEAD PRESSURE,1000 PSI FINAL WELLHEAD PRESSURE -WELL IS 60 PSI OVERBALANCE TO 10.0 PPG RESERVOIR AT 6515'TVD -WELL TO BE FREEZE PROTECTED TO 2200' MD/TVD POST RIG 20:30 - 22:00 1.50 WHSUR P WHDTRE MIRU WELLS SUPPORT LUBRICATOR CREW AND RIG UP. PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH TO LEAK-TIGHT CRITERIA (PASSING TESTS). SET 4"CIW TYPE H BPV. PRESSURE TEST BPV FROM BELOW TO 250 PSI LOW FOR FIVE MIN AND 3500 PSI HIGH FOR 30 MIN(PASSING TESTS,SEE ATTACHED CHART). RDMO LUBRICATOR CREW. 22:00 - 00:00 2.00 WHSUR P WHDTRE SECURE TREE WITH PROPER ANNULUS OUTLET EQUIPMENT AND CLEAN CELLAR. RELEASE PARKER 273 RIG AND END CON EVENT AT 23:59 ON 7/24/2013. NEXT WELL= Z-68 WELLWORK TRANSFER PERMIT CLOSED OUT WITH PAD OPERATOR WELL HANDOVER COMPLETE WITH WELLS GROUP ALL TREE AND WELLHEAD VALVES CLOSED TO GAUGES FINAL T/I/O PRESSURE=0/0/0 PSI CEMENT ESTIMATED TO BE 12'3"BELOW CONDUCTOR OUTLETS PERFORMANCE SUMMARY: 22.29 TOTAL DAYS VERSUS 25.08 AFE DAYS, 24.7 TARGET DAYS 17.2 DAYS/10K VERSUS 16.9 D/10KAFE,16.5 D/10K TARGET $7.95MM TOTAL COST VERSUS$9.254MM AFE,9.121 MM TARGET 24.5 HRS/$250K TOTAL NON-PRODUCTIVE TIME(4.5%) (1)RECORDABLE/DAFWC INJURY • )14 Printed 8/5/2013 1:42:26PM m 101p M1 " NMN 7 M0 1p 2MN N� 0 � NNO.C7 oD�.-Vvm Y.1 M10Afp aDhN 10w m 2 �D "VVM l7N 10""Y17 Mil Ol 5 iii "O�" r A I�A AMD 2 1A" € Mil 555i; Mil lis i it 55555 Mil MI a Y aYYa YaaYY YYOYY RW4Vz aY aaaYY aY�Y}aa Y♦O YY a qq p , 1 S N10O�1y1 p O�0)M" YNO T10 2418 N " Ot00 N "^N 8 9• S N 1 M(py ..I 5 N 17 M 2 4 1 5 N E d M N A 8 ��e Os1200 oo�ss � � ILA ^8Qoo �B�Y N M Wa is. � � SSN� � � as N N0NN NNNNN ^0000 120200 00022 COCOAO A2OwO0012^ 0000 POOR W e NmgEN m :,<SV8�0fgfp8 ;-,'.2.94gppn1 ^Rnito ppea,8 i7,78i8(en gsaa{ZN ryMn�{0ppr tq cAv g0m1Pn 1�Smpmm2 OYi010101N 6-52015 OHO'01202 al Ra 1001 W W0 82880 110V 12 aN W 51EEE EEEEE EEEEE !IEEE EEEEE EEEEE IREll lit§ C.,132201gi 171Ti1•ly; 1704,,wN x2,2s svpiv 842,4x v2,4A, 2Vrt, • mm2 mmmml mmm�i I���,�, �mmI 22222 Imm�M "p�a "10""N ""if."0"1 0000" 0000" 0000 ""10"" "N 0000 O't2p. gn..NN E V.2ON N5�Ag OEDANN "NO2O mem W N N1M.ICON 10000 004000 000,0 ',ONO. 0.-00 0.-002 . .i 1V.-N 00.., O• Sg OMS 6.8040.,2 ON0O W MQO21�0 3283 N 2 W 2FtM0 r(OE V o 8117-62C000n- .-04011 Y h10"1N 12120404E m 0,,IA" T.�,R4 90niM1= v r.NN 1 2 CScOo0000 OC7 V 2r ♦mN.N-m mm V 1m•1A $tA•IIA•IOYNI ON10n0 g744'$ 0091212o .00002 oo20. 9To.. 0-9.. 9,--- -51d7H ;mug v s a 2 v C r. 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OmFr.mr �V22 00 I§'±' F2YRAN �rc1CF V..a ON o Vm to 22022 (fr Or� r 200 �N to O_ i to co (V 0 Cl H 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,October 29,2013 Jim Regg �j P.I.Supervisor 1�e I7 t(( /i3 SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC Z-114 FROM: Lou Grimaldi PRUDHOE BAY UN BORE Z_-114 Petroleum Inspector Si-c: Inspector Reviewed By: 1'.1.Supry .7173e— NON-CONFIDENTIAL , !3NON-CONFIDENTIAL Comm Well Name PRUDIIOE BAY UN BORE Z-I 14 API Well Number 50-029-23490-00-00 Inspector Name: Lou Grimaldi Permit Number: 213-065-0 Inspection Date: 10/22/2013 Insp Num: mitLGl31023075946 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i Z-t 14 1Type Inj w' TVD 6348 - IA 442 2534 . 2499 - 2488 - PTD 2130650 Type Test SPT Test psi 1587 OA 491 696 688 678 . Interval INITAL P/F P Tubing 625 625 625 624 Notes: Fluid to Surface,5.2 bbl methanol pumped with 4.5 returned.Good test.All pertinent documentation supplied. A-4-4(160461,4-% weft SC til2a trx Ii'c. — � Recsues Pi at Tuesday,October 29,2013 Page 1 of 1 TREE= 4-1/16'QW W91ffA0= MC Z-114 SAFETY NOTE: CHROME HIPP LEs ACTUATOR= 03W LBO OKB.REV= 102.05' I BF.ELEV= 54.5' KOP= 2767' Mex Angie= 69 ©5356' Datum A,O= 10062' Il N 1846' —14-12'NES X NP(SCR),D=3.813' Datum TVD= 6600'SSI GAS LF?MANDRELS 20'CONDUCTOR, 1291,X-56,0=19.124' 128' ST MD ND Ota/ TYPE VLVVLV LATCH PORT DATE 3 2843 2642 7 KBG DMY BK 0 10/01/13 9-5/8-CSG,40N,L-80 BTC,0=8.835' H 318T —A 11, 2 6670 5021 68 KBG DMY BK 0 0723/13 1 9600 8294 38 KBG DMY BK 0 10/01/13 ESTIMATED TOP OF CEMENT — 3884' S.• ii '♦ _ Net , e3r —14-12'FES X NP(SCR),D=3.813' Minimum ID =3.725" fp 9774' �. r 0 4-112" HES XN NIPPLE (9CR) ; i� 4i _ _ or —{T x 4-12'FES TNT PKR 0=3.870' ♦ S. Y L 1704' —14-12NP(M 'FES X GR),D=3.813' II No 1 J♦ 9774' H4-12'FES XN NP(SCR),D=3.725' 6 Ns. F♦ 4-12'TBG, 12.81,L-80 TCI, 97611' \ t� 97'91' —4 12'WLEG 0=3.958' .0152 bpf,ID=3.958' H f3.h0 TT LOGGED NOT LOGGED N vi • N. f• 11$02` --i2 10`MARKER JTS w/RA TAG i N' Y' FERFORATION SILM'.RY N REF LOG SLB MSF/BC ON 722/13 N ANGLE AT TOP FERF:25'@ 9658' N. N Note:Refer to Production DB for hisbricai perf data N SIZE SPF NTERVAL Opn/Sgz SHOT SOZ N 2-718' 6 9858-9906 0 09/23/13 N• Y♦ X N 0♦ N Fi N V N. ,Fi V v PBTD 10162' �11�����•�� I♦ sd11/1111111111111111114 T CSG,281,L-80 VAM TOP HC, H 10235' 11111111111 ' ►�1,1.1.1.1_1�1:1.1.1, 1 .0383 bpf,0=6.276' DATE REV BY COMFITS DATE REV BY COM ENTS PRUDHOE BAY INT 0729/13 PKR 273 INITIAL COMPLETION WELL. 2-114 08/01/13 JM) DRLG FD CORRECTIONS FERMT No:`1130650 09/18/13 W RJM)GLV 00(09/15/13) AR Pb: 50-029-23490-00 10/04/13 SET/J943 ADFERFS(09/23/13) S& 19,711N R12E 716'FM_&1472'PM. 10/04/13 GJB/JM.) GLV 00(10/01/13) 10/09/13 PJC PERFORATION CORRECTION BP Exploeatbn(Alaska) ++1 11 S I • ry I . I , I • • .-- 11./) .4) t•A Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWelllntegrityCoordinator@bp.com] Sent: Wednesday, October 23, 2013 9:54 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Wallace, Chris D (DOA); AK, OPS Well Pad Z; Oshiro, Joleen; AK, RES GPB East Wells Opt Engr; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: OPERABLE: Injector Z-114 (PTD#2130650) Passing AOGCC witnessed MIT-IA All, Injector Z-114 (PTD#2130650) had a passing AOGCC witnessed MIT-IA on October 22,2013, demonstrating two competent barriers and satisfying regulatory requirements. At this time the well is reclassified as Operable, and may remain online as needed. Regards, Laurie Climer BP f 11 Alaska - Well Integrity Coordinator GG►obai Wens w►7 Organizats n WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, October 08, 2013 10:35 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; K, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; D. •"el, Ryan; AK, D&C Wireline Operations Te. • Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West We Opt Engr; 'chris.wallace@alaska.gov'; AK, •• Well Pad Z; Oshiro, Joleen; AK, RES GPB East Wells Opt Engr Cc: AK, D&C DHD W- tegrity Engineer; AK, D&C Well Integrity .• dinator; 'jim.regg@alaska.gov' Subject: UNDER EVALU ' •N: Injector Z-114 (PTD #2130650) Ready • Place on Injection Pre AOGCC MITIA All, Injector Z-114(PTD#2130650) is a new well - is ready to place on injection. The wel . •ssed an MITIA to 4200 psi on the rig and a MITIA to 2500 psi on 10/1/2013. Th- •.ssing test confirm two competent barr . s in the wellbore. The well is reclassified as Under Evaluation so it can be pla .• on injection in preparation for an AO c witnessed MITIA. Plan forward: 1. Operations: Place well on injection 2. Fullbore: AOGCC witnessed MITIA once well is thermally stable. Please call with any questions. M 13 ' Mil VON . I 6Ma MiN0 m ;HU' 0NMm2 niN m m La ChV F 2gmmg HARE mmmm$ 22mm6 mnmm m22 RIM nm0m d ^as O J mmpmmm mmm mmm mmmmmmmdm0 mmmmm m 4444 E d 1NrCN V , N V 22662 N42p Dmmm3282E 2y022 NNNOV 20.18121 nNp. 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Mm ,,:ii 0 rV ON '(;- 1- 0 H0 W W m W J pp N W mM OO L%cf, e ^m m E=00 tOg roLL h N n O O N N NNm N M M a n aa, Via as a O O '2200? m0 f 0 N N N e e M m N N N N N N IL °2.°21:-. a O i n _,:2 Q 2 M m 2 LL y N .-LL UMS Eva O XNe mNNN m n 0O n467 2%8 O y J N NOOa6NMIO4n .LCm m aim aaao 00 Yvl Cqio 0 7. o o cG E U o c IL Q E >> s V mm 2 H1t4 f Pry Z4306sb Regg, James B (DOA) From: Madsen, Alan D [AIan.Madsen@BP.com] Sent: Tuesday, July 16, 2013 6:42 PM To: DOA AOGCC Prudhoe Bay; Turner, William; Conatser, Royce (PRA) Cc: Kilfoyle, Jeffery A; Daniel, Ryan; Allen, Kenneth W; Rossberg, R Steven; Cismoski, Doug A; Schultz, Mikel; McMullen, John C; Reem, David C Subject: BOP usage form Attachments: Z-114 BOP usage form Parker 273.doc Guys, Please find the enclosed BOP usage form for Parker 273 during operations on Z-114. -' «Z-114 BOP usage form Parker 273.doc» Alan Madsen GPB Rotary Field Superintendent Cell 306-4997 Slope office 659-4618 Anchorage office 564-5780 Harmony 2156 (As a phone--Dial, 1-907-659-3106 then 1 then 758-21560) Those who turn their swords into plows will be ruled by those that don't. 1 Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Alan Madsen Wellsite Leader Name: Will Turner Contact Number: 659-4618 Contact Number: 659-5880 Traction Number: IR-4474811 Well Location/Name & Rig Name: Z Pad Z-114i Parker 273 Permit To Drill (PTD) Number: 2130650 Date and Time of Incident: 07/16/2013 00:30 am Original Scope of Work: Drilling ahead in intermediate 8 3/4 hole section. Operational Description Leading up to Well Control Event: While drilling 8 3/4" intermediate hole the driller was alerted to a gain by his Pit Volume Totalizer for his active system. He picked up and performed a flow check. The well was flowing so he shut it in and made all the proper notifications. The well was circulated out using the driller method with no signs of gas. An exhale test proved the flow was due to wellbore breathing and after circulating bottoms up, drilling resumed. BOPE Used and Reason: Annular Preventer. The well was flowing during a flow check. Is a BOPE Test Required after use ( Yes / No): Yes — If no, why? 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Continue to drill ahead to TD. Circulate well POOH and run intermediate casing. Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bavCcr�alaska.uov Email CC List Well Integrity Team Leader: WTL HSE Advisor: Engineering Team Leader: _ Wells Operations Manager: Wells Intervention Manager: Organizational Capability BOPE Usage Report for AOGCC Rev 1 September 1, 2010 w,1, V/7., THE STATE Alaska Oil and Gas Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue rh: ALAS Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Ken Allen Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU Z-114 BP Exploration (Alaska), Inc. Permit No: 213-065 Surface Location: 4564' FSL, 3480' FEL, SEC. 19, T11N, R12E, UM Bottomhole Location: 4730' FSL, 1804' FEL, SEC. 18, T11N, R12E, UM Dear Mr. Allen: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, (j4 Cathy V. Foerster Chair DATED this 1 day of May, 2013. RECEIVED STATE OF ALASKA ALAS. JIL AND GAS CONSERVATION COMM. .ON MAY 0 9 2013 PERMIT TO DRILL 20 AAC 25.005 A GCC 1 a.Type of work: 1 b.Proposed Well Class: 0 Development Oil ❑Service-Winj ®Single Zone . 1 c.Specify if well is proposed for: ® Drill - 0 Lateral 0 Stratigraphic Test ❑Development Gas ❑Service-Supply 0 Multiple Zone ❑Coalbed Gas 0 Gas Hydrates 0 Redrill ❑Reentry 0 Exploratory ®Service-WAG ' 0 Service-Disp 0 Geothermal 0 Shale Gas 2.Operator Name: 5.Bond ®Blanket 0 Single Well 11.Well Name and Number: BP Exploration(Alaska) Inc. Bond No 6194193 ' PBU Z-114 • 3. Address '6.Proposed Depth: 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 10259' ' ND6852' ' Prudhoe Bay/Pru e-B r'. 4a.Location of Well(Governmental Section): 7. Property Designation(Lease Number): (r /�G Surface: `� 4564'FSL,3480'FEL,Sec. 19,T11N, R12E, UM • ADL 028262 • i� r /<.(3. Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 696'FNL,3080'FWL, Sec. 18,T11N, R12E, UM June 20,2013 Total Depth 9.Acres in Property: 14.Distance to Nearest Property: 4730'FSL, 1804'FEL,Sec. 18,T11N, R12E, UM 2560 9600' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 101.45' feet 15.Distance to Nearest Well Open Surface: x 599193 • y-5959360 • Zone- ASP4 GL Elevation above MSL: 54.5' feet to Same Pool: 1600' 16.Deviated Wells: Kickoff Depth: 2750' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 68 degrees Downhole: 3370 • Surface: 2719 • 18. Casing Program Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 20" 129# X-56 120' Surface Surface 120' 120' 260 sx Arctic Set(Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3153' Surface Surface 3153' 3151' 1527 sx DeepCrete, 330 sx Class'G' 8-3/4" 7" 26# L-80 VamTop 10258' Surface Surface 10258' 6852' 318 sx LiteCrete, 183 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: ®Property Plat IS BOP Sketch IS Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch ❑Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and correct: Contact Ryan Ciolkosz,564-5977 Printed Name Ken Allen Title Engineering Team Leader Email Ryan.Ciolkosz@bp.com Signature �',�--------" Phone 564-4366 Date J/9,4''i Commission Use Only Permit To Drill,! ..5-�.,/cAPI Number: Permit Appr I t See cover letter for Number: CA'" 50-ti 2-i-Z-D��(•i ct.J't l� 3 other requirements: Conditions of Approval: If box is checked,well may not be used to explore for,test,or pro uce coalbed methane,gas hydrates,or gas a Other: e15p f z-a f fo 4-f DO,'7 -b Samples Req'd: 0Yes g Req'd: shales: [�No Mud Log Req'd: ❑Yes lErNo /c70(.v p weiG//C kf a/ VC c/ o r L /00X7 H2S Measures: a4 Yes ❑No Directional Survey Req'd: D'Yes ❑No per-- Q .4 A C 2 S•03 3 (j ) , . Spacing exception req'd: 0 Yes lliNo inclination-only svy Req'd: 0 Yes ErNo -51-GLtG W fK x'55 r'a.✓ ,AA1 T r-en v� �'YU,/ a- f7 k- Sc/brI/3c-df�r�Vljcot7 V i APPROVED BY APPROVED BY et f -i �'�f� —COMMISSIONER THE COMMISSION Date - / /— l Form 10-401 Revised 10/201/ / This pe t i r f icrn sfrom the date of approval(20 AAC 25.005(g)) Submit Form and At achm is Duplicate 1� � 1313 To: Alaska Oil &Gas Conservation Commission From: Ryan Ciolkosz, ODE Date: May 8, 2013 Re: Z-114 Permit to Drill The Z-114 well is scheduled to be drilled by Parker 273 in June 2013. The grassroots well is high angle WAG injector targeting the Kuparuk C and A sands. The planned well has two hole sections. Surface casingwitl,be set in competent shale in the lower SV1 to isolate the permafrost/running gravels and ✓ hydrates. The injection hole is planned as a casing string set below the Kuparuk formation in the --Mituveach shale. The maximum anticipated surface pressure from the Kuparuk A sands with a full column of gas from TD to surface is —2719 psi (assumes 9.95 ppg KA5/6 as max pore pressure). This well will be drilled by Parker 273 using their 5000 psi four preventer BOP stack (3 rams and an annular preventer). The BOP rams will be tested to 4000 psi and annular preventer tested to 3500 psi. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on Z-114, please do not hesitate to use the contact information below. Ryan Ciolkosz Office: 907-564-5977 Cell: 907-244-4357 Email: rvan.ciolkosz(a bp.com Attachments: Well Schematic Directional Plan Z-114 Conductor As-built BOPE Equipment Schematics Diverter Line Layout Diagram Z-114 PTD Page 1 5/8/2013 Planned Well Summary et Well Z-114 Well WAG injector Object ve Kuparuk Current Status Grass Roots Well Estimated Start Date: 06/20/2013 Time to Complete: 28 Days Surface Northing Easting Offsets TRS Location 5,959,359 599,192 4564' FSL / 3480' FEL T11N R12E sec 19 Northing Easting TVDss Offsets TRS Tgt 5,964,680 600,732 -6360' 696' FNL / 3080' FWL 11N 12E sec 18 TKC4 BHL 5,964,828 600,775 -6750' 4730' FSL / 1804' FEL T11 N R12E sec 18 Planned KOP: 2750' MD/2648' TVDss Planned TD: 10,258' MD/6750' TVDss Rig: Parker 273 BF-RT: 47' RTE (ref MSL): 101.45 Directional — Schlumberger P21 KOP: 2800' MD _ Maximum Hole Angle: -68° in the 8-3/4" Hole section Close Approach Wells: All offsets pass major risk analysis Survey Program: Surface to-1200 ft MD = GYD-GC-SS (single shot gyro) or MWD+IIF+MS if clean surveys -1200 ft MD to TD = MWD+IFR+MS Nearest Property Line: 9,600 ft Nearest Well within Pool: -1600 ft to Z-113 Z-114 PTD Page 2 5/9/2013 Formation Tops & Pore Pressure Estimate Estimated Most Likely Depth Fluid />/4k„e u?-.J mMJ Formation Pore ( Formation Top Pressure Uncertainty Type G (TVDss) (EMW ppg) (+/-TVD ft) (for sands) G1 260 8.4 +/-10 ft. Permafrost . S _ SV6 1,020 8.4 +/-10 ft. Permafrost EOCU 1,570 8.4 +/-10 ft. Permafrost SV5 1,660 8.4 +/-10 ft. Permafrost BPRF 1,740 8.6 +/-10 ft. Permafrost SV4 1,780 8.6 +/-10 ft. No__ SV3 2,255 8.6 +/-20 ft. ydrafes SV2 2,450 8.6 +/-20 ft. Hydrates SV1 2,780 8.6 +/-20 ft. Hydrates 7, =� 9 5/8"Surf Csg 3,050 8.6 +/-20 ft. UG4 3,090 8.7 +/-20 ft. Coal CC':,, UG4A 3,130 8.7 +/-20 ft. Heavy oil Fault#1 (HSF) 3,330 8.7 +/-100 ft. MD UG3(Faulted) 3,330 8.7 +/-20 ft. Heavy oil UG1 3,810 8.7 +/-20 ft. Heavy oil UG_MA 4,110 8.7 +/-20 ft. Wet UG_MB1 4,165 8.7 +/-20 ft. Wet UG_MB2 4,225 8.7 +/-20 ft. Heavy oil UG_MC 4,305 8.7 +/-20 ft. Wet NA 4,370 8.7 +/-20 ft. Wet NB 4,395 8.7 +/-20 ft. Wet NC 4,430 8.45 +/-20 ft. Wet NE 4,440 8.45 +/-20 ft. Wet NF 4,500 8.45 +/-20 ft. Wet OA 4,550 8.45 +/-20 ft. Wet OBA 4,620 8.45 +/-20 ft. Wet OBB 4,650 8.45 +/-20 ft. Wet OBC 4,710 8.45 +/-20 ft. Oil OBD 4,770 8.45 +/-20 ft. Oil OBE 4,840 8.7 +/-20 ft. Oil OBF 4,885 8.7 +/-20 ft. Wet OBF_BASE 4,940 8.7 +/-20 ft. No CM2 5,260 8.7 +/-40 ft. No Fault#2(ZPad Flt) 5,700 9.5 +/-100 ft. MD No /0„2.-- CM1 (Faulted?) 5,700 9.5 +/-40 ft. No TLBK 6,005 10 +/-40 ft. No Fault#3 6,130 10 +1-50 ft. MD No THRZ 6,165 10 +/-30 ft. No TKLB 6,320 10 +/-30 ft. No TKC4 6,360 7.54 +/-30 ft. Oil/Gas TKC3E 6,370 7.54 +/-30 ft. Oil/Gas TKC2A 6,385 7.54 +/-30 ft. Oil/Gas TKC1C 6,420 7.54 +/-30 ft. Oil/Gas TKB/LCU 6,430 9.95 +/-30 ft. Oil/Gas TKA6 6,505 9.95 +/-30 ft. Oil TKA5 6,515 9.95 +/-30 ft. Oil TMLV 6,560 10 +/-30 ft. No TD 6,750 10 +/-30 ft. No /O '`7_ ,c,i/-,3 Z-114 PTD Page 3 5/8/2013 Casing/Tubing Program Hole Casing/ Wt/Ft Grade Conn Length Top(ft) Bottom (ft) Size Tbg O.D. (ft) MD/TVDss MD/TVDss - 20" 129# X-56 - 120 Surface 120/66 12-1/4" 9-5/8" 40# L-80 BTC 3153 - Surface 3153/3050 8-3/4" 7" 26# L-80 VaHCop 10258 • Surface 10258/6750 Tubing 4 1/2" 12.6# L-80 TCII 9760 Surface 9760/6294 Mud Program Surface Hole Mud Properties: Drilplex Spud Mud 12-1/4" Hole Section Density PV YP API FL Chlorides Funnel Depth Interval ppg (cp) lb/100 ft2 m1/30min mg/I pH Viscosity sec/qt 0'—Section TD 8.5-9.4 • 30-50 40-80 10 <1000 10.8 60-120 Injection Hole Mud Properties: LSND 8-3/4" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (PPM 3152'-8758' 8.8-9.4 12 - 18 20-28 <6 NC <18 9- 10 8758' -TD 10.2-10.4 - 12-22 20-28 <4 <10 <20 9- 10 Logging Program 12-1/4"Surface: Sample Catchers- not required for surface hole Drilling: Dir/GR/Res • Open Hole: None Cased Hole: None 83/4" Intermediate: Sample Catchers—as required by Geology Drilling: _ Dir/GR/Res/Neutron/Density - Open Hole: None Cased Hole: CBL Cement Program Casing Size 9-5/8"40#, L-80 Surface Casing Lead: Open hole volume+ 350% excess above BPRF, 40% excess below BPRF. Port collar Basis: used if hole conditions dictate Lead TOC: Surface Tail: Open hole volume +40% excess+ 80 ft shoe track Tail TOC: 800 ft MD above casing shoe Total Cement Lead 503 bbls, 2824 cuft, 1527 sks of 11.0 ppg DeepCRETE, Yield: 1.85 ft3/sk Volume: Tail 68.5 bbls, 382 cuft, 330 sks of 15.8 ppg Class G, Yield: 1.16 ft3/sk Casing Size 7" 26#, L-80 Injection Casing Basis: Lead: Open hole volume+ 30% excess Lead TOC: 1000' MD below 9-%" casing shoe Tail: Open hole volume+ 30%excess+ 80 ft shoe track Tail TOC: 1000' MD above casing shoe Z-114 PTD Page 4 5/8/2013 Total Cement Lead 176 bbls, 981 cult, 318 sks of 11.5 ppg Litecrete, Yield: 3.08 ft3/sk Volume: _ Tail 38.1 bbls, 214 cuft, 183 sks of 15.8 ppg Class G, Yield: 1.17 ft3/sk Surface and Anti-Collision Issues Surface Shut-in Wells: Z-103i Requires Shut-in to move Parker 273 over/off of Z-114 well slot SI/freeze Protect Z-113 and Z-115 45 days prior to spud to minimize production off take in the area. Hydrogen Sulfide Z-Pad is considered an H2S site. Recent H2S data from the pad is as follows: / Well Name H2S Level Reading Date Comments #1 Closest SHL Well H2S Level Z-103 NA-injector NA #2 Closest SHL Well H2S Level Z-116 NA-injector NA #1 Closest BHL Well H2S Level Z-113 12 ppm 5/10/2012 #2 Closest BHL Well H2S Level Z-115 NA-new well NA New Well #3 Closest BHL Well H2S Level Z-108 20 ppm 12/31/2012 #4 Closest BHL Well H2S Level Z-112 24 ppm 5/6/2012 Max.Recorded H2S on Z-100 120 ppm 3/2/2010 last reading 40 Pad/Facility ppm on 1/20/12 Faults Formation Where Encounter Fault MD TVDss Throw Direction Uncertainty Lost Circ Intersect Intersect and Magnitude Potential Fault#1 (Highland State Fault)-UG3 3,439.0 3,330.0 SW; 130 ft. +/-100 ft.MD Low Fault#2(Z Pad Fault)-CM1;faulted 8,759.0 5,700.0 West;200 ft. +/-100 ft.MD Low top) Fault#3-HRZ 9,552.0 6,130.0 South; 10-20 ft. +/-50 ft.MD Low Fault#4(not penetrated) 600 ft. N/A N/A North;20-40 ft. N/A Low north at TD of plan Fault#5(not penetrated)ZPad Fault N/A N/A West;200 ft. N/A Low at Kuparuk depth Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject . at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for . injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal/Contact the GPB Environmental Advisors (659-5893) for guidance. Well Control The 12-1/4" surface hole will be drilled with a diverter. (See attached diverter layout) The 8-3/4" section will be drilled with well control equipment consisting of 5,000 psi working pressure pipe rams (2), Z-114 PTD Page 5 5/8/2013 blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4000 psi (3500 psi Annular Test). BOP test frequency for Z-114 will be 14 days with function test every 7 days. Except in the event of a significant operational issue that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. 8-3/4" Intermediate Interval Maximum anticipated BHP 3370 psi at @ TKA at 6,515'TVDss (9.95 ppg EMW) Maximum surface pressure 2719 psi (.10 psi/ft gas gradient to surface) 25 bbls with a 12.8 ppg frac gradient Kick tolerance Assumes a 0.5 ppg kick intensity over the anticipated 9.95 ppg pore pressure at interval TD with a 10.4 ppg MW. Planned BOP test pressure Rams test to 4000 psi/250 psi Annular test to 3500 psi/250 psi Integrity Test—8-3/4" hole LOT after drilling 20'-50' of new formation below previous shoe 7" Casing The upper VBRs will be changed to 7" rams to accommodate the 7" casing. Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past -�--- the larger rocks and wood sections, the flow paddle will be put back in the flow line (<1000 ft). Procedures/Safeguards with paddle removed: • Fluid levels will be monitored in the pits for both gains and losses while drilling. Alarms will be set to indicate if gain or loss of more than 5 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • The planned 8.5-9.4 ppg fluid will provide over balance to formation fluid. Z-114 Drill and Complete Procedure Summary Pre-Rig Work: 1. Inspect Cellar Box and 20"conductor 2. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 3. Slickline SBHP on Z-115, obtain BHP on Z-113 via Down Hole Pressure Gauge 4. SI/freeze Protect Z-113 and Z-115 45 days prior to spud 5. Z-103i shut-in for Rig move. ESD installed while Parker 273 is operating on Z-114. 6. If necessary, level the pad and prepare location for rig move. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU. Nipple up diverter spool and function test diverter. 2. Prepare pits with Drillplex Mud and PU DP as required and stand back in derrick. 3. MU 12 1/4" drilling assembly with MWD/GR/Res and directionally drill surface hole to TD in the SV1. Perform wiper trip at the base of permafrost. CBU and condition hole as necessary, then POOH for casing. 4. Run and cement 9-5/8" 40# BTC surface casing. A TAM port collar may be run at 500' as a contingency. 5. ND diverter and NU casing / tubing head. NU BOPE (Configured from top to bottom: annular preventer, 2-7/8"x 5-1/2"VBR, blind/shear, mud cross, 2'/8"x 5-1/2"VBR). Test BOPE to 250 psi low, Z-114 PTD Page 6 5/8/2013 4000psi high with appropriate test joint (3500 psi Annular Test). Give the AOGCC 24 hrs notice prior to testing. 6. Make up 8-3/4" drilling BHA with MWD/GR/RES/AZI-DEN/NEU/PWD and RIH to float collar. Drill out shoe track and condition LSND drilling fluid. Drill 20' of new formation and perform LOT. 7. Drill to ± 200' above the CM1 ensure mud is conditioned and properly weighted (10.2-10.4 ppg) for shale stability, and perform short trip as needed. --- 8. Drill ahead to target TD, (below top TMLV). Ensure LWD/MWD has logged entire Kuparuk formation before calling TD. Circulate and condition fluid. Back-ream/MAD Pass as required over Kuparuk and Schrader Sands, short trip to TD and then POOH on elevators to run casing. 9. Change 2-7/8" x 5-1/2"VBRs to 7" rams and test with 7" test joint to 250 psi low, 4000 psi high prior to running casing. 10. Run 7" production casing and cement. Displace with 10.4 ppg NaCL/NaBr. Bring TOC to —1000' MD below the surface casing shoe. Bump plug and ensure that float holds. Pressure test casing to 4000 psi for 30 minutes. 11. Change 7" casing rams to 2-7/8" x 5-1/2" VBRs and test with 4-'/" test joint to 250 psi low, 4000 psi high. 12. Freeze protect 7"x 9-%"annulus after cement reaches 500 psi compressive strength. 13. RU SLB E-line. Log CBL from PBTD to Surface(AOGCC Requirement) 14. Run 4-Y2" L-80 completion w/3 GLM and land tubing hanger. RILDS. 15. Reverse circulate clean brine followed by corrosion inhibited brine for IA. Drop RHC ball and rod on rollers and set packer as per Halliburton recommendation and test tubing to 4000 psi and annulus to 4000 psi. Shear the DCK valve and pump both ways to confirm circulation ability. 16. Install and test TWC to 3500 psi from below. Nipple down the BOPE. Nipple up and test double master valves to 5000 psi. RU DSM and pull TWC. 17. Freeze protect the well to 500' TVD by pumping diesel down IA, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 18. Install BPV in tubing hanger and test to 3500 psi from below. Install all annulus valves and secure the well. Ensure that T/IA/OA have two barriers in place. RDMO. Post-Rig Work: 1. Install tree with Electric safety valve. Pull BPV. 2. R/U Slickline and pull ball and rod/RHC. 3. Replace the DCK shear valve with a dummy GLV. 4. Perforate post-rig with e-line 5. R/U Slickline Drift/Tag and obtain SBHP 6. Flow back to portable separator 7. Water Injectivity Step Rate test below fracture gradient 8. Install wellhouse(s) and flowline(s). 9. Pump RG2401 (Blue-Goo) on top of surface casing cement. Z-114 PTD Page 7 5/8/2013 Z-114 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. OverBurden: Shallow Gas to the north of Z-114 surface hole. Maintain standoff from gas by following V directional plan to the south intersecting the highland state fault below the surface casing point. B. OverBurden: Formation pressures are expected to range from 8.45 — 8.7 ppg down to the CM2. The Schrader sands are expected to be mostly wet with OBC, OBB and OBE being oil bearing. Ugnu Sands may contain Heavy oil and Hydrates are expected in the SV3 — SV1. The CM2/CM1 has a predicted pore pressure of 9.5 ppg. C. Kuparuk Reservior: The pore pressure in the Kuparuk C sands is anticipated to be under pressured i due to offset well production with limited injection support. The anticipated pore pressure is 7.54 ppg and contains oil and gas. However, the Kuparuk A sands are expected to be normally pressured at 9.95 ppg and contain oil. II. Lost Circulation/Breathing A. Surface Hole: Lost circulation is considered a minimal risk if mud properties remain in specification. B. Injection Hole: Breathing and/or lost circulation is a possibility due to 3 fault crossings. The highland state fault has been crossed in offset well at similar depths without issues. The Z pad fault has been penetrated in nearby wells Z-19A and Z-115 without issues. Fault#3 has not been crossed before, but is expected to have a small offset. There are also 2 faults near the Z-114 wellbore that establish the drillers polygon. If lost circulation becomes a problem, follow the LCM decision tree provided in the drilling program. Utilize good hole cleaning practices to avoid high ECD and prevent pack-off potential which could induce breathing. C. Injection Hole: Differential pressure in Lower Colville (overpressure), Kuparuk C (depleted pressure) and Kuparuk A sands (normal pressure). ✓ III. Integrity Testing Test Point Test Depth Test type EMW(lb/gal) 9-%"Shoe 20'-50'from the 9-5/8"Shoe LOT 12.8 ppg minimum(25 bbls) IV. Hydrogen Sulfide A. As Z-Pad is considered an H2S site, refer to the ADW "Hydrogen Sulfide" SOP for the appropriate operational guidelines. The max recorded H2S readings on the pad were 120 ppm in Z-100 March 2010. V. Faults Formation Where Encounter Fault MD Intersect TVDss Throw Direction Uncertainty Lost Circ Intersect and Magnitude Potential Fault#1 (Highland State Fault)-UG3 3,439.0 3,330.0 SW; 130 ft. +/-100 ft. MD Low Fault#2(Z Pad Fault)-CM1;faulted 8,759.0 5,700.0 West;200 ft. +/-100 ft. MD Low top) Fault#3-HRZ 9,552.0 6,130.0 South; 10-20 ft. +/-50 ft. MD Low Fault#4(not penetrated) 600 ft. N/A N/A North;20-40 ft. N/A Low north at TD of plan Fault#5(not penetrated)ZPad Fault N/A N/A West;200 ft. N/A Low at Kuparuk depth VI. Anti-Collision Issues A. The closest wells to U-16 are: Z-103 (11ft), Z-116 (19ft) at their closest points. All wells pass major risk criteria CONSULT THE Z-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. Z-114 PTD Page 8 5/8/2013 TREE_ ¢116• Z 114 WELLHEAD= FMC ACTUATOR= Electric KB.ELEV= 10.45 BF.ELEV= 54.5 KOP= 2800 Max Angle= 68 = 500' 9-5/8'TAM PORT COLLAR(IF Datum MD= 8833 -r I Required) Datura TVD= 6600'SS 1 2013' I--4'1/2'HES X NIP,ID-3.813' 20"CONDUCTOR,129#,X-56,D=19.124' --�_ 120'..---_ 9-5/8"CSG,40#, L-80 BTC, ID=8.75' — 3153' }— , Planned TOC -4153 GAS LWT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT LI3 2850 2850 2 KBG DMY RK 0 2 6619 5000 68 KBG DMY RK 0 1 9590 6259 40 KBG DMY RK 0 1 1 9620' -4-112 HES X NP,ID=3.813' S g 9650' JH7-X 4-1/2'HES TNT PKR ID=3.870' 1 1 9680'J-4-1/2 FES x NP,ID=3.813• 1 9745' —4-1/2'HES XN NIP,ID=3.725' 4-1/2'TBG, 12.68,L-80,TCII, .0152 bpr,13= 3.958' 9760' W LEG -9760' PERFORATION SUMMARY REF LOG: LWD ON ...9797 I—RA TAG&2x 10'MARKER,ITS ANGLE AT TOP PERF: Note:Refer to Production DB for historical pert data — SIZE SPF INTERVAL Opn/Sgz DATE r PBTO — 10173' i4 0r.♦ VVVVV T CSG,269,L-80,VTHC,.0383 by/,ID-6.276' — 10259' g•••••• •' DATE— REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 01/25/13 RRC ORIGINAL DRAW(Dir P21) WELL:Z-114 PERMIT No: ��---�_-------.— __ API No: SEC19 T11N R12E FSL 4563'FEL 3480' __ — BP Exploration(Alaska) M 0 pp1_ a) C 17 OM)p00,0M)T pM)pM)pM)OM)OM) .No.mm n NMb.N- W MmppppCOCO V O,N0 M 1`1 N N N N N N N N N c7.No. 6.6 N e} ui r M cp o N t7 ill O 6 d N m m m m m m m m m m m m 01 m O 606.6 O O N M N t 0 r NNNNN NNNNN N N N N N W m p)mmm mm m m m0000. m 0 0 0 0 00000 0 0 0 0 0 mmmmm mmmmm 00000 m 0000 00000 mmmmm a NNNNN N N N N N N N NNN N N N N N 00001, NNNNN N. M 01^ 0 0 0 0 0 00000 0)000 p MN N.} 00,0,* ON N M N 00 0.0000 100000 01.,00V p NNNN 00 mm 00M00 0 C = 00000) 00000 000 m 00 m 0)\1')0 OOMN p {p 00)N N V N O M M M M M M M M M M M M M M 0) M M 0)M M V Q Q p 0) Q Q 0 0)0 N 2 mmmmm mmmmm mmm0N O) 0,0,0,0) 0,N0,mm VM 0MMOm N N N N N N N N N N N N 00,0mN 100000 U) N0 N N N N m m)m0 U)) 0,0000 Nm IL))U)) 0 100)mm q )/ 0 0 0 0 0O O O O O 00,V,'- N O r p D D r r r m m m M t 0 N N r , 000000 00000 o m O r. M V e.V N CON-0,-1- M N r m 0 O , 00000 00000 .0,-,-N N N N nj N N M nl 1.l M M M M V a7, E Cm O w....- 0000 0 0 0 0 O O O O O 80800 p O p O p O O O 00000 J Z 0 0 0 0 0 0 0 0 0 O O O p 0 0 0 0 O N Y)t6 t0 00000 00 0000 00000 Nl\jN N N N ONNN NQQpa{ Q V Q V V 422 EE F^ fg��g g�ggm 2 MMM 7 N� nrn nNN�o n7wnn o 0 0 0 0 0 m m m m p? m m rn rn m = 5=2= 2=5== M M=2 S 3:' (0 O 10 O VJ O 0 N O N OJ 1p N N(O w C q N J NN p d ;) 0r m M Q Z (380 .88 O O > O)F O W O O O O O 00000 0 0 000 -m-.-N ry O m m^ 0.0O3-,-. m m O nn�II > 01-. °2m °0) 0 E C N N 0 0 0 0 0 6606. 0 0 M N 0 0 0 0.- c66.-Lows M Q h Or m r r 0- L E .O F O m . a C e 0 1- . .-e Z,L90r0NN. Ef Z0nE00 , 00 = ▪ O, 00460, 000206 d' N N 617 m F 0-3 d Z COO O O O00008 O O OQO Q r N.tO 0 0NrO jO0,Ui} L 00000 00000 O )N00 o: aim60; '1,00—mm m m O Yo N NNMMM VQrmm O M m N CO Yr a L 2 L6 2 .E E2 rE O .OHD yr ; 5 c E • E N f . Q u N 0 > y a •• N U 5q C C t mow, a`y E� To m d w°v_d 0 ° w o �We O C O U W C C d LL ` �w„ C d C Z y U O O 0 O O 00000 ry M O N n r p.-Q N Q N, m m M,—. W MI U 0 0 d d 7•-IL U Q q'- l� w O)LL. w_ 00000 00000 O m 0,M N .00N 10070 e'.} ,-V mN0 O J V V y y W?.'d a0 W ��D 0 0 0 0 0 6666. OtjM O N N Mr,M� ONr OND. O V m V O W Ai w y a s 5 C G C O t yy> a-,-,-NM Q W _ N p7 w w E g c U 2 U d C 8 0 (0 c aTi i E . z amt.-02 . .•mm V UU a to ZCYOOmo 33 �v o)C ms ,q, u an d , d w> > w > 0 o g w q o _ 00 a O h»F Fy22FF2Of 2 C7FJ o O w G_ O V V?OO M rN NQ MRVVV V VO6 >111 ON ^ mmmAOV TmV OnR? O MD CO ,p Nr0,.-NNVVVIO M.-N, mmor . NM 00,-W C 13 - - NNNNNNNM M MNMMMMMMM M M M M M 0 a 3 40 N O. . N o 0 0 0 0 0 0 0. N p 0 M m L p OOQO Noopry r�raDM v l i W z v.0 0 0 0 0000.1 p ,00 y r.m pp 0,p,c, a n m a m a m m.-o ` G p bN Orm V 0h)l)Q .0.01':a00) �0 fOfpp)ppjm).0j ImO ONi ONi tOj npj 031,-00M mNa Nr Zilli7N000 '^N V t0 t0nrmm p 000r NMM M V N(pr N N N N N N N N M M M M M M M M M M M M M m M w V. �_ LL_ N ` .II mow MOM00 Q 2- 00000 00000 Amo W m pp) mmm0 mm10000 W aaciwo 66666 00 mm 2 RI NN . rn 2 N- O 41 gW : Y0 > - ` 0 L. N m100 Q Q O Q CO M W M 1 {)a 0 0 0 0 0 (zoom. O M 0 0 0 0 tD 0 O r.- D m m p a} m 0 m 0 0 0077. n p O m g N 0 c- 00000 00000 9,0000 0 R 0.N 1`1 r c))0 N r N r N N O ""N O N N Y 4 m 00000 0 6666 1lj M Nr 0 07006 o N .^ 64 Mr1r - - N rQ r)ll r NM . 7jmVVm0000 N . VXNVo n am0xtONNrnQ0 . mMO WaQCCNM0O0pEm Wd20wmNg 0, n maNEEm ,.- zzzoo 2- O Q p p p Q p 0 0 0 00000 r-.-O mm00,<,.- 0 0 0 0 0 6.-:. t. .: )p O 0N..000 N ).l0<.j N OOA 0) 00000 0 N^0 ,C0000 N 00000 ^ r p)0M r 00 c•-,F) 00000 M N� mmMNr 0.0.0 NN NM V.r•p 00,00E = ryN NryNMM M c7MMM MMMmm MMMMM r To & r-----'"W 0 y� ` 1 I (O 0 . j( v l0 K C W C — \ N w.§ VV1 6 G O NJ > D N d G O 'Th 112 U 3L47) A N O0, . A UVw O C r. Y t ¢ Do 317-ii 0)o7iE t 0 Ug Ons — 2-'ii Z Z C O u o N D E W NUN u0)v MNa !;O a N a Q' V j M C m m o a 0 0 0 0 0 0 0 1-,- 0›. q>»n N) 0 c t 0 0 .) q(D ce0w0smQ/o Nr-0,00 0 c,0' OWO 00000 0 o)WU> > 0 0 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Site PB Z Pad Project: Prudhoe Bay TVD Reference: Z-114 Plan P273 @ 101.45usft(Parker 273) Reference Site: PB Z Pad MD Reference: Z-114 Plan P273 @ 101.45usft(Parker 273) Site Error: 0.O0usft North Reference: True Reference Well: Plan Kup Z-114(27+45)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan Z-114 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#21 Z-114 current Offset TVD Reference: Offset Datum Reference Plan#21 2-114 current Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 5.O0usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,221.20usft Error Surface: Elliptical Conic Survey Tool Program Date 1/28/2013 From To 1 (usft) (usft) Survey(Wellbore) Tool Name Description 46.95 1,200.00 Plan#21 Z-114 current(Plan Z-114) GYD-GC-SS Gyrodata gyro single shots 1,200.00 3,153.00 Plan#21 Z-114 current(Plan Z-114) MWD MWD-Standard 1,200.00 3,153.00 Plan#21 Z-114 current(Plan Z-114) MWD+IFR+MS MWD+IFR+Multi Station 3,153.00 4,650.00 Plan#21 Z-114 current(Plan Z-114) MWD MWD-Standard 3,153.00 10,258.96 Plan#21 Z-114 current(Plan Z-114) MWD+IFR+MS MWD+IFR+Multi Station li 1/28/2013 11:09:58AM Page 2 of 6 COMPASS 5000.1 Build 61 • by Schlumberger WELL Z-114 (P21) FIELD Prudhoe Bay Unit-WOA STRUCTURE Z-PAD Magna.Panniers Surface 1084)8.1 NAM)Naaka State Pin.Zone 04.US Feel MecNMneo.a Model 8GGM 2012 Op 80.977• Data: September 20,2013 Let N 701754.273 No.%. 5953359 89 Grid Cary.0.158• Sloe Slot(slot 104) TVD Ret Rotary Tabb(101458 above MSL) Map Dec'. 19 ser FS'. 57005.7117 Lon: W149 11 48 092 Easeng 589192 93 0))5 Stab Fact:0.99081118 Plan: Z-114(P21) Spry Date:January 28,2013 0 1000 2000 3000 4000 5000 0 tit 0 1000 1000 2000 .1 4 a 2000 • • Bld 2/100 3000 End Bid 3000 9-5/8"Csg Cry 2/100 • O Cry 4.5/100 O _.._.._._ G9(top faul[edj._.._.._.—..—.....—...........—..—....—.....—....._.._.......3.........—.....—..—.....-4—.....—..—. 'au/ti .—..—..—..—..—.—..—..—..—........—.._.. I I 0) (3 4000 _"_.._._.._.._.. 1.._.._.._..End•crr._.._.._.._....._.._................-..-..-..-_-..............-..-..- -.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.. 4000 4 i• ▪..m..= .•..••..••..••..••..•r•-• i by • Schlumberger WELL FIELD STRUCTURE Z-114 (P21) Prudhoe Bay Unit-WOA Z-PAD Magnetic Parameters Surface Location NADP Was.State Plana,Zone 04,US Feet Miscellaneous Model: 13GGM 2012 Dip. 80.977° Date: September 20,2013 Lat N 701754.273 NoMing. 595935989 80S Grid Cony:0.756° Slot-. Slot(slot 104) ND Ref: Rotary T3de001.4511 above MSL) Mag Deo 19.997• FS. 57605.7nT Lon. W1491140492 Fasting: 59919293500 Scale Fact 0.%991118 Plan. Z-114(P21) Sny Date:January 26,2013 -800 0 800 1600 2400 6400 0 6400 Z-114 Flt4 6500ss 7"Cs, 56005600 Z-114 Tgt 1 Kup 111%Z-114 Geo Poly DT 95% Witt Z-114(P21) `♦ Fault3 4800 4800 Z-114 Flt 3 6130ss Fault 2 Cr/el/100 4000 4000 z 114 Fite 5700ss A A A Z 0 0 0 3200 0 3200 a) V V V 2400 2400 1600 1600 800 a 800 End Cry Cry 4.5/100 Cry 2/100 9-5/8"Cs. Fault 1 0 End Bld 0 Bld 2/100 RTE Z-114 F01 3330ss -800 0 800 1600 2400 «< W Scale=1:800(ft) E >>> - o 0 am - o 0 m _ - o 0 N. 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N a 0 K ' . nN' V 00000 00000 v0NvOvvvmvvvgi . v000 @ 0V v mO ma . p0M m. .-mm @mNN- MMO �OWONN j 0SNOO qCOOOW 0000MQM CoMM0000MMMQQ QQ@Q@ @@@@@ @@@@@ @@@@00 00 00000 OID CO T IO m 0 L 0000NVpNpOSSS0 00000SSOOO 060VyNOQ0 00 WON0 W D, Wp 0 - 7 Cl O O^ 00 ONONON- 0a02NNmOSSVMVOONW0 { ONN0OO0NO a0O0^ WN' 0o-N? a ) W 60 CO ^ N O m0)M7 OMMM@ @0000 \ \OOO N ` OO0p 0O NM M M MM@@0 0 . + M Q@Q@ @@@@@ @@@@@ @@@@@ 00000 00000 OOOOO 000OO O000 CO 1` 00000 00202 O O O O O 00000 00000 00000 00000) 00000 0 0 0 0 0 00000 0 O O O C O O 000 0 00000 00000 00000 O O O O m 66666 66000 6.6 . 2 O 0?O O O O F (O6000NO OOb OCO NGNGNG bCa NONGNONONO NUNO NONONO NONONO1010 OOOO NO OONONOO 660 b NO 66666 CO E 0- 4 1---* "NNNN1p NNp NO O)m 00000 00)00010 00000 mO00)0O.Q VVVVR VVM12V VC^OV O 0) mV NMW o ...2.26 10 10 m 0l6O0 /00600060 0)60600)0) 66600 600KKK 6 0 016166 v O R@ 0)M MMM O N NNNNN N O {000000 00'@N' 1)OCNCO NRMCN 00lNO1) 00NN 0 00888 88,44,8 O V O O 2 ^0'4212 0 26666 Q 666:62 CN 66666 2 O66666 6626 0 0 0000 v00,-m0O61OCO 26262 DU0) UCOM0 0 N 00 qQOQ �OQQpN0D ry000 0000NMmONQ000)g0 m0) 00)0vV 000 000 000 W 0,-NM,, 00000 000 0 0 I O 1 CO O N r Y 0 O g c 2 m -8 U O E laC N°� M N UJ Q 0-1 0T E (C to 80 N 0 ma CIC..D OOm 0000)0 ��� 2 Y �N m @^M N 030) � �" m �� U'CU 0 U'OCO O U Z W Z ZZZZZ ZZ000 00000 ULLUO ti LLti 1- IY-NIY- ti tiI�-I-- 0 0 a; Ncoco, m tti ottrN dev O_ W o�o oo 2 p O 0 O O tptoO D t UD t D CO coo CO (7 0) t o O t t D O o O t cN t7CO.oLL, ve7m 0 L vLr, i 4tam CO 0•' r n m 0 to too CDD coo 6 t6o tpo m rn rn In Li,co to h� Km 0 C W 00,O)o O O O 0 O C NNh CO (0(D to c u_ 0 0 p O p 0 O p o J�" p O p 0 0 0 0 CI O V Q R Q V R V LL o U) CO (I)V) 00 H-- J J J J J J OO C 0)n coot O 4.W t[0)ccoo () 0 W•-• p to CO o N O N N oi MOM R V h to 0 to CO U)to 0 IV C m to c hr o c.)c C,CI O_ Z ocl tno r-o co 400(D'n v ri r Qo CO 0 0 of co hLC,CV h O A V O '1 to to IV W e-OR COD CD NN tU c6 4�� CD rim{p a_tO h t o h t o a 0 h N o o m R M t7 V 10 CO to DI CO y0j to co to(0)0 0 CO to CD D (0 0 O L N0)O O V 0 0 CO o 2 CD co m 01 to LOa (0cof0 92 r. w N a(0(0 0 (0(0 CD Z N_ H CD f0 tp t0 tU tp t0 E i- m? J D LL J N W p t7 7tri tri cO N CV N 7 7 N LL co r LL O t0 CO L C lA tS to 0 O p(O Q N J 2— t7 OIO .co 01 o' O N lD 0 O( D- O 00 O O NO N NO N , o dm 0 • N N (O la N U) 0 0 E 0) h ti J U U0 • PARKER 272 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP �i 13 5/8"-5M FLANGED BOTTOM =I1I W/(2) 14" UL2 OPERATOR, UPPER CAVITY 0 0 SHAFFER ANNULAR XOTP13 5/8"-5M AND (2) 14" PSLK W/BSTR OPERATOR, ` ' ' ' • ' 1 LOWER CAVITY 13-5/8" 5M STUDDED TOP 0 13-5/8" 5M FLANGED BOTTOM 0 I I DRILLING CROSS: I I 13 5/8"-5M FLANGED TOP IIIQ� I to 13 5/8"-5M FLANGED BOTTOM _ ,.0-.0 W (2) 3 1/8"-5M SIDE OUTLETS i • �J ---- C — �^ I I ° e °°Q} I I E I �1 I KILL LINE: 2-1/16" 5M FLEX HOSE / -�"�� III I. sk° , \ >5( - 2-1/16" 5M X 3-1/8" 5M D.S.A. " A 3-1/8" 5M FLANGED MANUAL GATE VALVE ,v 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE • ..•. C 3 ■ ■ 00 I I CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP 5M FLEX HOSE 13 5/8"- 5M FLANGED BOTTOM 3-1/8" W/(2) 14" UL2 OPERATOR • ^ z 1---------......„ >l9" t " s 7 1 ,,,, c--- \ , / o°oo \ V-PAD ,4 'c) j), \ 1\.,,.2) (( 1 S) 35 ■ 1 \ I�.1 1'n ,. n C.) J �\\ - ba 67i■ —N— GRID i • - '' I • ". SPINE RD 9 ■ ■ 33 .4 `p :LY` ` ,� `' L W'.! 7 ■ ■ 31 6 ■ ■ 30 Z PAD \ l .I 115 •■ /' ■ 29 �, 1 108 ■ j ■ 210i 4 ■ 1 1 i 218r THIS PROJECT ,,' .. •-; Q >ra 3 ■ ( ■ 27 } �-' 2 • t ,1404i 1031 V",°-'44 1 ■ ■ SPARE-Ar ® ■ P-504A \ 3 "sOL.,ls,. ■ P-5046 1 f. .�" , 1 4 VICINITY MAP I ,��%��71lli�,'' NTS i __.._.......—_ ..__ ♦ 0 F ■ 22 �_C).° °° °`���°S°,„'T SURVEYOR'S CERTIFICATE 39 ■ 11 ■ IF a 23 � *° 4 9 m \ °',* I HEREBY CERTIFY THAT I AM PROPERLY j •.;,, o o,,, ,,,,\ REGISTERED AND LICENSED TO PRACTICE 12 ■ • 24 dip (�° °°°°°°°°°/ LAND SURVEYING IN THE STATE OF ALASKA / y -1 g, AND THAT THIS AS-BUILT REPRESENTS A 13 • ■ 25 I°°°°° °y. ° °°°°°° °°°• SURVEY MADE BY ME OR UNDER MY VP DIRECT SUPERVISION AND THAT ALL 14 II ■ 26 • `'hard . Allison z DIMENSIONS AND OTHER DETAILS ARE ■ SLOT 1 I °°°o `gr CORRECT AS OF AUGUST 16, 2005. 15 ■ I ■ SLOT 2 `r'�°°° 1 Q 8 17sslow- ■ _.. ■ 1L1• 1T 4 �,I''i,ge°^f°°°°°°\- ♦�`� b. 17 ■ , ,�r1�V1 �LE �`� i9 i Z—PAD GEND 20 ■ AS-BUILT WELL CONDUCTOR RENAMED ■ EXISTING WELL CONDUCTOR RENAMED CONDUCTOR REVISION NOTE WELLS: SPARE—B & SPARE—C NOTES: 1. REFERENCE FIELD BOOKS: W004-13, W004-16, W004-19. THIS AS-BUILT DRAWING IS A REISSUE OF A 2. DATES OF SURVEY: SEPT., NOV. & DEC., 2004. PREVIOUS AS-BUILT DRAWING FOR CONDUCTORS 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. SPARE-B & SPARE-C. RENAMED CONDUCTORS ARE AS FOLLOWS: 4. PAD AVERAGE SCALE FACTOR IS 0.999911213. OLD COND. NAME NEW COND. NAME 5. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. SPARE—B Z-114i 6. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. SPARE—C Z-1041 7. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTATION. 8. REFERENCE DRAWING FRB05 WOZ 02 FOR ORIGINAL CONDUCTOR RENAME. LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 12 E., UM IAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y=5,959,359.76 N= 2,127.18 70°17'54.274" 70.2984094° 4,564' FSL 1041 X= 599,177.83 E= 2,129.78 149°11'48.532" 149.1968144° 53'8' 3,495' FEL Y=5,959,359.89 N= 2,112.08 70°17'54.274" 70.2984094° ' 4,564' FSL 114i 54.5 X= 599,192.93 E= 2,129.91 149°1 1'48.091" 149.1966919° 3,480' FEL I DRAWN. F. Robert- oRBARNHART 444 0 :ire CH :WOLFID DA71°'2W0 E: �Jyi 1/26/11 ` 14 %%•/J DRAWING: z FRB11 WOZ 06 WOA Z—PAD SHEET, p rasSoC. JOB No. RENAMED AS—BUILT CONDUCTORS °"_ 9'M'� SCALE. 1 OF 1 00 1/26/11 ISSUED FOR INFORMATION TFB JZW r e 200. WELLS: Z-1041 Sc Z-1141 NO. DATE REVISION BY CHK_ riw wx. t. --- I 1 C - - r ' ,,..____,.____..j...„1 PIPIP'.01 1 i. (R... i�i. �Il71 !9���� !"[ ' 11 1 � lY[ :1 ii_��.� "I / \ ...,. 9, 1�% `�—___• 0 i ‘ . 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Iv. �y A co '' CO.1. iki u t_i vir 1 .., , 1 i 1 I1L1 •(D (� s � .•SP.V .�,n . _, 'r,-�n Cil I L. & 94 '—� [� Yk ''��,f: L't��nn —JAVA& .1 ' - -.mow" CD 84•.' MP CAD cob _ _.. L_.'' ...�_ - • • - t� �p :w.v{. 6000 i� ) ' i TRANSMITTAL LETTER CHECKLIST WELL NAME "(L C --1/V PTD# 2-77 3 Development /Service Exploratory Stratigraphic Test Non-Conventional Well / FIELD: Xi/6-e_, / POOL: IC/'` Check Box for Appropriate Let r/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. • Rev:9/09/2011 T15 U usn a) n Y 0 0 a) 0 0 6 NN 7 2 i .) C U 3 • Q a) N U n O T n - X (0 a) E c O O 2 C w co N a) o) Q L n o i- n n WL 0 w N c Oo Y U) O 0 o Xa) C() a) E O bc O l4 0 a) m 0 0 0 a 2 E oLL vE U co 0 Ec aa a o U to a (SD T _c 2 a) (O .0 > @ N = O a r N a O a) 3c. N Q E 7 D >O N a) E co O co p n N O' O 3 M a) a tri O (0 rn O _O 0 N n N 3 N d w o n c ?' 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