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HomeMy WebLinkAboutO 089INDEX OTHER ORDER NO. 89 Failure to complete a Mechanical Integrity Test Milne PT Unit SB G-19 Area Injection Order 10B Milne Point Unit 1. September 24, 2013 NOV Missed MIT of MPU MPG-19 2. October 16, 2013 Response from BPXA 3. November 20, 2013 AOGCC's response INDEX OTHER ORDER NO. 89 1�1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501-3539 1Ze: Failure to complete a Mechanical Integrity Test (MIT) Milne PT Unit SB G-19 (PTD 2041920) Other Order No. 89 Area Injection Order 1013, Milne Point Unit (MPU) January 211,2014 FINAL DECISION AND ORDER On November 20, 2013, the Alaska Oil and Gas Conservation Commission (AOGCC) issued a Notice of Proposed Enforcement Action (Notice) to BP Exploration (Alaska) Inc. (BPXA) regarding the Milne PT Unit SB G-19 (MPG-19) well. The Notice advised that BPXA failed to complete a Mechanical Integrity Test (MIT) in MPG-19 well. The Notice proposed a $11,500 civil penalty under AS 31.05.150(a). In reply to the notice of enforcement, BPXA provided a letter dated December 10, 2013 not contesting the proposed enforcement action and enclosed a check in the amount of $11,500 in payment of the civil fine. A. Summary of Proposed Enforcement Action The Notice identified a violation by BPXA of Rule 4 of Area Injection Order 1013 (AIO 1013) ("Demonstration of Tubing - Casing Annulus Mechanical Integrity"). A violation occurred every day after March 17, 2013 that BPXA injected into MPG-19 without completing an MIT, specifically September 1, 2, and 3 2013. The AOGCC proposed payment by BPXA of a civil penalty under AS 31.05.150(a) in the amount of $11,500 ($10,000 for the initial violation - failure to perform the required MIT of the injection well in compliance with Other Order 489 Page 2 of 4 0 January 21, 2014 testing protocols specified in Rule 4 of AIO 1013, and $500 for each day September 1, 2013 to September 3, 2013 (3 days) for injecting in a well out of compliance with MIT regulations) B. Demonstration of Tubing/Casing; Annulus Mechanical Integrity Rule 4 of AIO 1 OB states "A schedule must be developed and coordinated with the Commission that ensures that the tubing -casing annulus for each injection well is pressure tested prior to initiating injection,.following well workovers affecting mechanical integrity, and at least once every./bur years thereafter. " The last AOGCC-witnessed MIT occurred March 17, 2009. Therefore an MIT was required on or before March 17, 2013. No MIT was timely performed. The well was out of compliance, but continued injection for 3 days, from September 1, 2013 to September 3, 2013 inclusive. BPXA failed to demonstrate the mechanical integrity of injection well MPG-19 within the required four year cycle, a violation of State regulations and AIO 1 OB. C. Violation An MIT on MPG-19 was required no later than March 17, 2013. By email dated September 5, 2013 BPXA notified the AOGCC that MPG-19 was returned to injection on September 1, 2013. In the BPXA October 16, 2013 letter in response to the AOGCC investigation, BPXA provided data specifying that injection occurred on September 1, 2, and 3, 2013 (3 days) before BPXA shut in the well. Other Order #89 • Page 3 of 4 D. Mitigating Circumstances • .January 21, 2014 The AOGCC considered the factors in AS 31.05.150(g) in determining the appropriate penalty. The penalty was reduced due to BPXA's general history of satisfactory compliance and practices, an aquifer exemption for the MPU, the lack of actual or potential threat to public health or the environment, and BPXA's immediate shut-in of the MPG-19 once BPXA determined the well was out of compliance. E. Findings and Conclusions The AOGCC finds that BPXA violated the regulations and the Rules in AIO JOB governing the Demonstration of Tubing -Casing Annulus Mechanical Integrity. Mitigating circumstances outlined above were considered in the AOGCC's Notice of Enforcement Action and its assessment as to the appropriate civil penalty, which was decreased from the maximums provided by statute. BPXA did not contest the AOGCC's proposed enforcement action, paid the civil fine, and established and implemented training and process protocols for employees and contractors governing injection operations and management of change. The AOGCC finds BPXA's new training and process protocols to be satisfactory effort to help prevent further occurrence of this violation of failure to complete a Mechanical Integrity Test. NOW THEREFORE IT IS ORDERED THAT: BPXA shall: 1. Comply with the AOGCC's regulations, orders, approved administrative actions, and approval conditions relating to injection for enhanced recovery purposes. Other Order #89 • Page 4 of 4 0 January 21, 2014 2. Implement and update as necessary the training and process protocols governing Mechanical Integrity Testing and injection operations and management of change outlined in BPXA's October 16, 2013 letter. 3. Maintain and make available for AOGCC inspection records to substantiate completed training for BPXA personnel as outlined in BPXA's October 16, 2013 letter. Done at Anchorage, Alaska and dated January 21, 2014 4 /�� �� - Cathy P. oerster, Chair, Commissioner Alaska it and Gas Conservation Commission Daniel T. SeamAurft, Jr., Commissioner AlaskrOil and Gas Conservation Commission 'NOrffian, Uommissioner Oil and Gas Conservation Commission RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Raker, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Singh. Angela K (DOA) From: Colombie, Jody 1 (DOA) .sent: Friday, January 24, 2014 1:11 PM To: Singh, Angela K (DOA); Ballantine, Tab A (LAW); Bettis, Patricia K (DOA); Brooks, Phoebe L (DOA); Carlisle, Samantha 1 (DOA); Colombie, Jody J (DOA); Crisp, John H (DOA); Davies, Stephen F (DOA); Ferguson, Victoria L (DOA); Foerster, Catherine P (DOA); Frystacky, Michal (DOA); Grimaldi, Louis R (DOA); Hunt, Jennifer L (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Eaton, Loraine E (DOA); Bender, Makana K (DOA); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA); Norman, John K (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); Turkington, Jeff A (DOA); Wallace, Chris D (DOA); (michael j.nelson@conocophillips.com); AKDCWeIIIntegrityCoordinator; Alexander Bridge; Andrew Vanderlack; Anna Raff; Barbara F Fullmer, bbritch; bbohrer@ap.org; Barron, William C (DNR); Bill Penrose; Bill Walker, Brian Havelock; Burdick, John D (DNR); Cliff Posey; Colleen Miller, Crandall, Krissell; D Lawrence; Daryl J. Kleppin; Dave Harbour, Dave Matthews; David Boelens; David Duffy; David Goade; David House; David Scott; David Steingreaber; Davide Simeone; ddonkel@cfl.rr.com; Donna Ambruz; Dowdy, Alicia G (DNR); Dudley Platt; Elowe, Kristin; Evans, John R (LDZX); Francis S. Sommer; Frank Molli; Schultz, gary (DNR sponsored); ghammons; Gordon Pospisil; Gorney, David L.; Greg Duggin; Gregg Nady; gspfoff, Jacki Rose; Jdarlington oarlington@gmail.com); Jeanne McPherren; Jones, Jeffery B (DOA); Jerry McCutcheon; Jim White; Jim Winegarner; Joe Lastufka; news@radiokenai.com; Easton, John R (DNR); John Garing; Jon Goltz; Jones, Jeffrey L (GOV); Juanita Lovett; Judy Stanek; Houle, Julie (DNR); Julie Little; Kari Moriarty; Keith Wiles; Kelly Sperback; Kiorpes, Steve T; Klippmann; Gregersen, Laura S (DNR); Leslie Smith; Lisa Parker; Louisiana Cutler; Luke Keller; Marc Kovak; Dalton, Mark (DOT sponsored); Mark Hanley (mark.hanley@anadarko.com); Mark P. Worcester; Kremer, Marguerite C (DNR); Michael Jacobs; Mike Bill; mike@kbbi.org; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; knelson@petroleumnews.com; Nick W. Glover, Nikki Martin; NSK Problem Well Supv; Patty Alfaro; Decker, Paul L (DNR); Paul Mazzolini; Pike, Kevin W (DNR); Randall Kanady; Randy L. Skillern; Randy Redmond; Rena Delbridge; Renan Yanish; Robert Brelsford; Ryan Tunseth; Sandra Haggard; Sara Leverette; Scott Griffith; Shannon Donnelly; Sharmaine Copeland; Sharon Yarawsky; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Smart Energy Universe; Smith, Kyle S (DNR); Sondra Stewman; Stephanie Klemmer, Moothart, Steve R (DNR); Steven R. Rossberg; Suzanne Gibson; Sheffield@aoga.org; Tania Ramos; Ted Kramer; Davidson, Temple (DNR); Terence Dalton; Teresa Imm; Thor Cutler, Tim Mayers; Tina Grovier (tmgrovier@stoel.com); Todd Durkee; Tony Hopfinger; trmjrl; Tyler Senden; Vicki Irwin; Vinnie Catalano; Walter Featherly; yjrosen@ak.net; Aaron Gluzman; Aaron Sorrell; Ajibola Adeyeye; Alan Dennis; Andrew Cater, Anne Hillman; Bruce Williams; Bruno, Jeff J (DNR); Casey Sullivan; David Lenig; David Tetta; Perrin, Don J (DNR); Donna Vukich; Eric Lidji; Erik Opstad; Gary Orr, Smith, Graham O (PCO); Greg Mattson; Hans Schlegel (hans.schlegel@ge.com); Heusser, Heather A (DNR); Holly Pearen; James Rodgers; Jason Bergerson; Jennifer Starck; jill.a.mcieod@conocophillips.com; Jim Magill; Joe Longo; Josh Kindred; King, Kathleen J (DNR); Laney Vazquez; Lois Epstein; Longan, Sara W (DNR); Marc Kuck; Marcia Hobson; Steele, Marie C (DNR); Matt Armstrong; Matt Gill; Franger, James M (DNR); Morgan, Kirk A (DNR); Pat Galvin; Bettis, Patricia K (DOA); Peter Contreras; Pollet, Jolie; Richard Garrard; Ryan Daniel; Sandra Lemke; Pexton, Scott R (DNR); Peterson, Shaun (DNR); Pollard, Susan R (LAW); Talib Syed; Todd, Richard J (LAW); Tostevin, Breck C (LAW); Wayne Wooster; Woolf, Wendy C (DNR); William Hutto; William Van Dyke Subject: APB - Milne Point Unit well MPG-19 (BPXA) Attachments: other89.pdf Jody J. Colombie Special Staff Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Jodie. ColombieAulaska.gov Office: (907) 793-1221 Fax: (907) 276-7542 • Michael P. Brock BP Exploration (Alaska), Inc. Post Office Box 196612 MS 3-1 Anchorage, AK 99519 David McCaleb Penny Vadla IHS Energy Group George Vaught, Jr. 399 W. Riverview Ave. GEPS Post Office Box 13557 Soldotna, AK 99669-7714 5333 Westheimer, Ste. 100 Denver, CO 80201-3557 Houston, TX 77056 Jerry Hodgden Richard Neahring Mark Wedman Hodgden Oil Company NRG Associates Halliburton 40818" St. President 6900 Arctic Blvd. Golden, CO 80401-2433 Post Office Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Bernie Karl CIRI Baker Oil Tools K&K Recycling Inc. Land Department 795 E. 94" Ct. Post Office Box 58055 Post Office Box 93330 Anchorage, AK 99515-4295 Fairbanks, AK 99711 Anchorage, AK 99503 North Slope Borough Planning Department Richard Wagner Gordon Severson Post Office Box 69 Post Office Box 60868 3201 Westmar Cir. Fairbanks, AK 99706 Anchorage, AK 99508-4336 Barrow, AK 99723 Jack Hakkila Darwin Waldsmith James Gibbs Post Office Box 190083 Post Office Box 39309 Post Office Box 1597 Anchorage, AK 99519 Ninilchik, AK 99639 Soldotna, AK 99669 2_�,Q • Randy Redmond Operations Full Field Onshore Site Manager Is RECEIVE® bp DEC 112013 A0GCC riy BP Exploration (Alaska) Inc. P.O. Box 196612 900 East Benson Boulevard Anchorage, Alaska AK 99519-6612 UNITED STATES OF AMERICA Phone:+1-907-564-4889 December 10, 2013 Certified Mail 7013 0600 0000 8040 0643 Return Receipt Requested Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Notice of Enforcement Action Failure to complete a Mechanical Integrity Test (MIT) Milne PT Unit SB G-19 (PTD 2041920) Area Injection Order 10B Milne Point Field, Milne Point Unit (MPU) Dear Commissioner Foerster: Enclosed is check # 193 payable to the AOGCC in the amount of $11,500 in response to the Notice of Proposed Enforcement Action dated November 20, 2013 to BP Exploration (Alaska) Inc. Please call me with any questions. Kind regards, Randy Redmond, PE Operations Full Field Onshore Site Manager Enclosure cc: Laney M. Vazquez, Senior Counsel (via e-maid BP Exploration (Alaska) Inc. MICHAEL P BROCK 89-6/1252 BP EXPLORATION AK INC pastercard Check" PO BOX 196612 MS 3-1 ANCHORAGE, AK 99519 DATE CJ 4 i3 AY 70 THE �JI/i -50o — 0O OR/DER OF LL..��V s L ✓e�, �'�d�.c ��� �,ve L,.w,cA,rec) C�¢ liCnrS cv", („t —B-0tCARS First National Bank Alaska Anchorage, AK 99510 / MEMO Ply-il✓ M!'f OJ(_,V --- ` -- A,4 NgkmsS 1: 1 P 5 2000601 99 1 1 1000 30 1 3I'm 0 19 3 � OF Tfj • THE STATE Akska, Oil and GEE GOVERNOR SEAN PARNELL November 20, 2013 Certified Return receipt 7012 3050 0001 4812 5689 Mr. Randy Redmond Operations Full Field Onshore Site Manager BP Exploration (Alaska), Inc. 900 E. Benson Blvd Anchorage, AK 99519-6612 Re: Notice of Proposed Enforcement Action Failure to complete a Mechanical Integrity Test (MIT) Milne PT Unit SB G-19 (PTD 2041920) Area Injection Order 1 OB Milne Point Field, Milne Point Unit (MPU) Dear Mr. Redmond: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 The Alaska Oil and Gas Conservation Commission (AOGCC) hereby notifies BP Exploration (Alaska) Inc. (BPXA) of a proposed enforcement action. Nature of the Apparent Violation or Noncompliance (20 AAC 25.535(b)(1)). The AOGCC believes BPXA violated the provisions of Rule 4 of Area Injection Order lOB (AIO IOB) ("Demonstration of Tubing -Casing Annulus Mechanical Integrity") in its operation of the Milne PT Unit SB G-19 (MPG-19) well. Basis for Finding the Violation or Noncompliance (20 AAC 25.535(b)(2)). On September 5, 2013 BPXA contacted AOGCC by telephone and subsequent email to report that well MPG-19 was brought back on line for approximately two days before BPXA discovered the well was operating without a current Mechanical Integrity Test (MIT) and shut it in. By letter dated September 24, 2013, AOGCC requested additional information. BPXA responded to the request on October 16, 2013. The information provided indicate the well was shut in on March 17, 2013, the 4 year MIT anniversary due date.. The information provided by BPXA (labeled Attachment 2, Pg 5) also shows injection occurred on September 1, 2, and 3 2013 without the required MIT. BPXA states "the well was discovered to be on line without a current MIT through a daily field -wide exception report which flags Not Operable wells which ■ Complete items 1, 2, and 3. Also complete lete p A Sign -L�Agent item 4 if Restricted Delivery is desired. X ^ ❑ Addressee ■ Print your name and address on the reverse so that we can return the card to you. g. R �*e,dPri d m�.` ate of Delivery ■ Attach this card to the back of the mailpiece, � y^^�, t�%it � or on the front if space permits. D. Is delivery address different from item 1? If YES, enter delivery address below: ❑Yes ❑ No 1. Article Addressed to: 3. Service Type Mr. Randy Redmond ❑ Certified Mail ❑ Express Mail Operations Full Field Onshore Site Manager ❑ Registered ❑ Return Receipt for Merchandise BP Exploration (Alaska), Inc. ❑ Insured Mail ❑ C.O.D. 900 E. Benson Blvd. 4. Restricted Delivery? (Extra Fee) ❑ Yes Anchorage, AK 99519-6612 2. Article Number 7 012 3050 0001 4 812 5689 (Transfer from service label) _. _ PS Form 3811, February 2004 Domestic Retiir, 102595-02-M-1540 Notice of Proposed Enforcemen*ion MPG-l9 • November 20, 2013 Page 2 of 3 are on line." As a result, on September 3, 2013 MPG-19 was shut in. On September 7, 2013 and September 9, 2013 MIT's were completed with passing results. Rule 4 of AIO 1 OB states "A schedule must be developed and coordinated with the Commission that ensures that the tubing -casing annulus for each injection well is pressure tested prior to initiating injection, following well workovers affecting mechanical integrity, and at least once every.four years thereafter. " The last AOGCC-witnessed MIT occurred March 17, 2009. Therefore an MIT was required on or before March 17, 2013. No MIT was performed before March 17, 2013. Though out of compliance the well was placed on injection for 3 days, from September 1, 2013 to September 3, 2013. BPXA failed to demonstrate the mechanical integrity of injection well MPU MPG-19 within the required four year cycle which is a violation of State regulations and AIO 1013. Proposed Action (20 AAC 25.535(b)(3). For these violations the AOGCC intends to impose civil penalties on BPXA as follows': $10,000 for the initial violation — failure to perform the required MIT of the injection well in compliance with testing protocols specified in Rule 4 of AIO 1 OB; $500 for each day September 1, 2013 to September 3, 2013 (3 days) for injecting in a well out of compliance with MIT regulations. The total proposed civil penalty is $11,500. Violations relating to Underground Injection Control Class II well integrity practices warrant the imposition of civil penalties. BPXA's failure to comply with the fundamental wellbore mechanical integrity testing requirements raises the potential for similar behavior with more serious consequences. Mitigating circumstances were considered in the assessment of the proposed civil penalty including the operator's history of satisfactory compliance and practices, the existing aquifer exemption of the MPU, the lack of actual or potential threat to public health or the environment, and BPXA's immediate shut in of the well once BPXA determined the well was out of compliance. Rights and Liabilities (20 AAC 25.535(b)(4)). Within 15 days after receipt of this notification — unless the AOGCC, in its discretion, grants an extension for good cause shown — BPXA may file with the AOGCC a written response that concurs in whole or in part with the proposed action described herein, requests informal review, or requests a hearing under 20 AAC 25.540. If a timely response is not filed, the proposed action will be deemed accepted by default. If informal review is requested, the AOGCC will provide BPXA an opportunity to submit documentary material and make a written or oral statement. If BPXA disagrees with the AOGCC's proposed decision or order after that review, it may file a 'AS 31.05.150(a) provides for not more than $100,000 for the initial violation and not more than $10,000 for each day thereafter on which the violation continues. Notice of Proposed Enforcementfion MPG-19 • November 20, 2013 Page 3 of 3 written request for a hearing within 10 days after the proposed decision or order is issued. If such a request is not filed within that 10-day period, the proposed decision or order will become final on the I I1h day after it was issued. If such a request is timely filed, the AOGCC will hold its decision in abeyance and schedule a hearing. If BPXA does not concur in the proposed action described herein, and the AOGCC finds that BPXA has violated or failed to comply with a provision of AS 31.05, 20 AAC 25, or an AOGCC order, permit or other approval, then the AOGCC may take any action authorized by the applicable law including ordering one or more of the following: (i) corrective action or remedial work; (ii) suspension or revocation of a permit or other approval; (iii) payment under the bond required by 20 AAC 25.025; and (iv) imposition of penalties under AS 31.05.150. In taking action after an informal review or hearing, the AOGCC is not limited to ordering the proposed action described herein, as long as BPXA received reasonable notice and opportunity to be heard with respect to the AOGCC's action. Any action described herein or taken after an informal review or hearing does not limit the action the AOGCC may take under AS 31.05.160. Sincerely, Cathy . Foerster Chair Commissioner cc: David Tetta, USEPA, Region 10 AOGCC Inspectors r� a Randy Redmond Operations Full Field Onshore Site Manager October 16, 2013 Via E-mail: jody.colombie@alaska.gov and Certified Mail, Return Receipt Requested Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: MPU MPG-19 (PTD 2041920) Area Injection Order 10B Milne Point Field Dear Commissioner Foerster, BP Exploration (Alaska) Inc. P.O. Box 196612 900 East Benson Boulevard Anchorage, Alaska AK 99519-6612 UNITED STATES OF AMERICA Phone: +1.907-564-4889 REDEiVIE D OCT 17 2013 AOGCC This letter responds to the Commission's letter dated September 24, 2013 requesting additional information regarding Well MPG-19. Well MPG-19 is a Schrader Bluff multi -zone injector. The well was off injection beginning December 17, 2012 due to matrix bi-pass events (MBEs). As shown on the enclosed schematic, the well has selective completions for injection through mandrels into the NB, NE, CA, and OB reservoir intervals. Frequently, valves are changed between these selective completions to alternate injection intervals and avoid MBEs. The well also has a history of produced water injection requiring periodic tubing cleaning or mild reservoir stimulations. After a change in selective completions, there was a misunderstanding by an operator in the field and the well was put on injection for approximately 48 hours before it was discovered, immediately shut in and the MIT -IA renewed. The well was discovered to be on line without a current MIT through a daily field -wide exception report which flags Not Operable wells which are on line. The well is on a 4-year MIT -IA testing frequency. BP Exploration (Alaska) Inc. (BPXA) investigated the MPG-19 incident and is taking measures to prevent reoccurence. BPXA is implementing a new requirement to install physical locks and tags on the wing valves of wells classified as "Not Operable." BPXA uses the "Not Operable" well status in its internal tracking system to flag injection wells which do not have a current MIT. This new lock and tag requirement is being implemented across all BPXA slope facilities through a Management of Change (MOC) process. The implementation process is expected to be complete within 90 days. BPXA defines the responsibilities of Wells, Operations, and Reservoir Development in its Well Integrity Operating Practice (WIOP). Pursuant to WIOP, it is the responsibility of Operations to Page 2 check the operability status before putting a well on injection. WIOP training is required annually for BPXA employees working wells. This training is being updated to include the new lock and tag requirement discussed above. BPXA has already conducted refreshed training for its MPU pad operators. The following further responds to the Commission's numeric requests for additional information: Please see the current wel►bore schematic, attached as Attachment 1. 2. Please see the TIO plot and raw data for the last 90 days, attached as Attachment 2. 3. Please see the well history and timeline detailing work completed since the prevous MIT dated March 17, 2009, attached as Attachment 3. 4. Please see an incident investigation summary attached as Attachment 4. BPXA is not aware of other missed MIT events. The daily field -wide exception report mentioned above would provide notice of any such events and is, in fact, how this incident was discovered. 5. Please see documentation of BPXA's MIT Tracking System, attached as Attachment 5. 6. Annual WIOP training is required for every BPXA employee working on wells. After the MPG-19 incident, all of the MPU Field Operators were immediately retrained on their WIOP responsibilities (18 employees on September 8-9, 2013 and 13 employees on September 12, 2013). Our automated training management system requires employees to take training modules systematically, testing is required to verify understanding, and it records participation for compliance. Presently, 1194/92% are current on WIOP training, and the remaining are expected to be current by the end of 2013. 7. Please see a summary of BPXA's Management of Change for revising WIOP to lock and tag "Not Operable" wells at all North Slope facilities, attached as Attachment 6. This change in WIOP has been communicated to BPXA employees via slope -wide e-mails, annual WIOP training intervals, and rolled out by Operations Field Leadership Teams slope wide and discussed as a lesson learned. Please let us know if you need additional information or desire a close-out meeting. For production operations matters I may be contacted directly at 564-4889 or contact Ryan Daniel at 564-5430 for specific well integrity issues on this subject. Kind regards, Randy Redmond, PE BPXA, Operations Full Field Onshore Site Manager THE STATE Alaska Oil and Gas o1Al 1 LASKConservation Commission GOVERNOR SEAL\ PARNELL 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 September 24, 2013 Certified Return Receipt 7009 2250 0004 3911 5891 Mr. Ryan Daniel Alaska Region Wells Integrity and Compliance BP Exploration Alaska, Inc. 900 E. Benson Blvd Anchorage, AK 99501. Re: Investigation of missed MIT of MPU MPG-19 (PTD 2041920) Area Injection Order IOB Milne Point Field Dear Mr. Daniel: On September 5, 2013 Randy Redmond, Operations Full Field OSM, with BP Exploration Alaska, Inc (BPXA)-contacted the Alaska Oil and Gas Conservation Commission (AOGCC) by telephone and subsequent email to report that well MPG-19 was brought back on line for approximately two days before BPXA discovered the well was operating without a current Mechanical Integrity Test (MIT) and shut it in. The email states that a MIT is being coordinated with the AOGCC site inspectors, and that BPXA has taken immediate action in initiating personnel progressive disciplinary action in not following procedures and practices, and to roll out additional training to clarify wits and responsibilities that ensure well status is verified and validated prior to flowing a well to prevent a re -occurrence. Pursuant to 20 AAC 25.300, within 30 days of the date this request is sent, the AOGCC requests the following additional information be provided: 1. Current wellbore schematic; 2. TIO plot and raw data for last 90 days; 3. Well history and timeline detailing work completed since last MIT dated 3/17/2009; 4. documentation of the completed BPXA incident review, specifically to verify that the investigation was broadened to review and identify all similar potential missed MIT scenarios across BPXA facilities; Investigation of missed MIT MPU MPG-19 September 24, 2013 Page 2 of 2 5. documentation on the BPXA MIT tracking system, procedures and practices, for determining when MIT's are required, including the contingencies for wells shut in at the time an MIT is due and its procedures for notification to the AOGCC, as well as it's procedures for determining the MIT due date and identification of past due wells; 6. proof or schedule detailing additional training (sign off sheets or affidavits); 7. documentation showing that BPXA has broadcast this incident and findings internally with the aim of increasing awareness and sharing the lessons learned. The AOGCC reserves the right to pursue enforcement action in connection with this investigation of well MPG-19 as provided by 20 AAC 25.535. cc: Thor Cutler, USEPA, Region 10 AOGCC Inspectors Sincerely, Cathy P. oerster Chair, Commissioner APPEAL As provided in AS 31,05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. if the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Radler, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it maybe appealed to superinr court That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOCJCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), " [tJhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on aweekcnd or state holiday - U.S. Po CERTIF (Domestic Mail Provided) For delivery information visi comp 0" Postage $ m Certified Fee Postmark ED Return Receipt Fee Here p (Endorsement Required) Restricted Delivery Fee l� (Endorsement Required) LI rU Total Postage ru SentTo Er" Mr. Ryan Daniel treef, AjiENo.; Alaska Region Wells Integrity and Compliance or PO Box No. BP Exploration Alaska, Inc. city state, ZIP+ 900 E. Benson Blvd. �6 rrA.nchors a AK 99501 - �SENDER: COMPLETE TH16'' ► ■ Complete items 1, 2, and 3. Also c�o:,,plete item 4 if Restricted Delivery is desired. ■ Print your name and address on the r so that we can return the card to ■ Attach this card to the back of or on the front if space perm 1. Article Addressed to: • Mr. Ryan Daniel Alaska Region Wells Integrity and Compliance BP Exploration Alaska, Inc. 900 E. Benson Blvd. Anchorage, AK 99501 2. Article Number (Transfer from service labeo PS Form 3811, February 2004 • 1. Signs, X 1� ❑ Agent ❑ Addressee D. Is delivery address different from item 1? '❑ Yes If YES, enter d 030 s w: ❑ No q��U� 9 ti d�5 3. S rvice Typ6 Certified Mail ❑ Express Mail ❑ Registered ❑ Return Receipt for Merchar ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 7009 2250 0004 3911 5891 Domestic Return Receipt 102595-02-M-1540 ; Tree: Cameron 3 1 /8" SM Wellhead: FMC 11 " X 3.5" gen 5 tbg hanger TC-II T & B thread. 3.5 CIW 'H' BPVT 20" 91.1 ppf H-40 114' 9 5/8" Weatherford Float Collar 3894' 9 5/8" Weatherford Float Shoe 3979 RA Tag 7 KOP @ 500' Max. hole angle = 70 deg @ 6000' Hole angle thru' perfs = . 3.5", 9.3 ppf, L-80 TC-II Tbg (cap. = 0.0087 bpf, drift = 2.867 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf RA Tag 7� Valves in SPM / XN: Arrangement as of 111 1111 Perforation Summary SWS Slim Cement bond log dated, 11/24/0 Size Spf Interval (TV' 4.5" 5 NB Sands 7,650' - 7,680' Sands 4,234' - 4,: 4.5" 5 NE 7,783' - 7,823' OA Sands 4,285' - 4': 4.5" 5 8,004' - 8,024' 4,367' - 4,: 4.5" 5 8,040' - 87080' OB Sands 4,381' - 4.2 4.5" 5 8,183' - 8,213' 4,436' - 4,, MPG-19i '- DATE REV. BY I COMMENTS 11/10/04 Lee Hulme Drilled & Cased by Doyon 14 01/01/05 MDO Perforate & Complete Nabors 4-es Orig. KB Elev. = 59.30' (D-14) Orig. RT-LDS Elev. = 30.27' (D-14) 5" HES X-Nipple (2.813" pkg) 2,035' i" x 1" Camco KBUG-M GLM 2,120' HES X-Nipple (2.813" pkg.) 7,525' x 3.5" Baker Premier Packer F77545' 5" x 1.5" Camco MMG-W GLM 7,571 ` 5" x 1.5" Camco MMG GLM 7,631' x 3.5" Baker Premier Packer 77751 ` 5" x 1.5" Camco MMG-W GLM 7,77T 5" x 1.5" Camco MMG GLM 7,838' x 3.5" Baker Premier Packer 1 7,960' ed P-15XJR 17164 395 BWPnI T set on 9/5112 @ 7987 5" x 1.5" Camco MMG-W GLM 1 7,987' 5" x 1.5" Camco MMG GLM 8,047' I x 3.5" Baker S-3 Packer 8,140' I 5" x 1.5" Camco MMG-W GLM 8,165' ded P-15XJR 16/64. 345 BWPDLT set on 9/6/12@ 8165 5" x 1.5" Camco MMG GLM 8,224 5" HES XN-Nipple (2.813" pkg.) 8,251 ` I' 2.750" No -Go ID 3.5., WLEG 1 8,264' 7" Weatherford Float Collar 8357' 7" Weatherford Float Shoe 8443' MILNE POINT UNIT WELL No.: MPG-19i API : 50-029-23228-00 0 r-I 4A CL 1 N s U Cp �--+ Q m 0 � 0 � N CY1 O (D N r \ 0 0 w <0 <00 0 0 0 0 �Ti fl m hA N O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o00�c0n000000000nr�00MMmmMmvNNNNmNNMMMMv c v m m m m m m m m m m m m m m m m m m M m m m m m m M m m N N m m m m m m m m m m m m m N N m m E V co +-J Q m 0 0" o 0 0 0 rl� S a o 0 0 N 0 0 0 0 0 0 0 0 0 0 0 000000 O O 'n lD .-i 0� * a' • -- -" -4 � a a 00 ' uo ID m a a V N N. r O O 2 o 0 0 0 0 0 0 0 0 N a fV N� V to Ln Ln m Ln �D N M r, r, r, r, v 'n Ln 0 Ln Ln 0 000 00 000 O O 00 cc O O 00 O 0 O 0 O 0 80000 O000rna DN m D D D Dr, MO00000�00000OOOOOOOOOOOOO000000 n wLnn � n oo n rn m o0 00 00 0o ao � 1D m m m m m M m m m m m m m m m m m m m m m m m m M m m m m m m m M m m m m m .4 1 -4 m m m m m M O O O O O O O o O O O O O O .--r .--r .-i ti .--i .-i . 0 0 0 O O O O O O O O o O O O O O o O O O O r ti N N N N N N N N N N N N N N O O O O O O O O O N N N N N N N N N N N N N N N NNNNNNNOO \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N N N N N N N N \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ N N V M \ \ N e-1 at a0 1D a m N \ \ \ \ \ \ O O1 00 n �D V1 V m .-� O Q1 W-00 r` �D 0 a M N O \ \ N N N N e-1 w. r.' rl V1 '-I 7* m .-1 �"� '-1 01 00 r� lD Ln M N � m M N N N N N N N NN N N 'i �--� ��-i �•" r �--1 �"r ti M 00 Y/ Ol Ol Ql 01 01 01 Ol Ql 01 01 Ql O1 Ol 01 Ol Ol Ql O1 Ol Ql 01 O1 01 00 00 W W �0 W W a0 �0 W 00 00 00 �0 W W 00 W �0 �0 W W 00 W /- V M. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Q 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q M M M V a V M N M V a O M O M M N M M m M m M M M M M M M N MM N N N a V OM N N M M N M m M M N M m M m m M m M M M M M m M M m M m M m M m M M m M m m m ' M M M M m m M M M m Q O O O O O O O O O O O O 00 O O O O O O O O O O O O O O O N N N N N N N O N o a-* 0 0 0 0 0 Vr R o C 0-t V-* N N-q C C a a N N N O O O O O O O cu QtoSS00SSSSSS00SSgg01-1 gg00 1-4 S0gS00S0S00S00S074 '.10 O\N+ N \N \N \N \N \N \ O 01 \ \ \ \ \ \ \ \ \ \ \\\\\\\ \ \ NN N N N N N N N \ \ \ \4\0 mmm -Mm'.4q OooOO -4 -4 M OOo O OOOO O O O oooNo00N 00000N N00N000N N N NOOO�OOOO NNN N N .4\00r D 1n a M N .-O M 00 r` tD 1n � mN-r O\ m 00 n %D 0m0 rmm\ md ma m Nmmti M mNN N N N N N N N NNrr N� ti-4 al 00 r� lD Ln � m N M N N N N 000000000\00\00\00\000000000nn�nnnnnnnnnn�nr r, r, nn����nnn�ID WIDW ........................................ 0 c R R N N R Ci I= c � ZB � 66 BS as B5 - ----- ---- ------ x tDo 0 Wild BWPD I MC;FPD cl� 1 clC,� F 73 L�l tm e � t9 r b5 zr) !;5� ;45 'AHM cu rn • C MPG-19 Well History Attachment 3 Source Well Date Description Purpose WellStatus MPG-19 Ol/Oct/2013 Inj press, psi: 1836 Type: PW Volume: 249 Monitoring T/1/0=1608/175/219 AOGCC MITIA PASSED to 2300 psi Pumped 1.6 bbls diesel down IA to test pressure. IAP lost 70 psi 1st 15 min, 20 psi 2nd 15 min PASSED AWGRSO MPG-19 09/Sep/2013 FWHP's=1600/0/220 Well on inj at dep, IA, OA=OTG Tags hung. Waived by AOGCC Chuck Scheve Integrity T/1/0=1500/180/210 Temp=115* MIT IA PASSED to 1500 psi. (Pre AOGCC) AWGRSPI MPG-19 07/Sep/2013 Pumped 2.5 bbls diesel down IA to reach test pressure, Loss of 47 psi 1st 15 min. Loss of 11 psi 2nd 15 min.FWHP=1500/0/27S SV shut WV,MV,SSV,IA,OA Open Integrity T/1/0=570/0/350 Freeze protect Inj. Line w/ 5 bbls 60/40 Freeze protect Tbg.w/ Freeze protect while AWGRSO MPG-19 04/Sep/2013 22 bblsw 60/40 FWHP's=1000/20/350 SV, WV, SSV=S/I MV=O IA, OA=OTG Lat scheduling MIT -IA and Valves=0 Tags hung pad op notified. performance enhancement "'CONT'D FROM 08-31-13 WSR"'PERFORM WEEKLY WLV TEST "PASS'*`RAN SBHPS AS PER PROGRAM**"GOOD DATA'**PULLED 1.5" RK- AWGRSN MPG-19 01/Sep/2013 DGLV & SET 1.5" P-15-XJR(light spring) IN ST#4 @ 7987' MDPULLED 1.5" RK- DGLV & SET 1.5" P-15-XJR light spring) IN ST#2 @ 8165' MDPULLED 3.5" WHIDDON @ 8238' SLM'*"WELL S/1 ON DEPARTURE**' Injection Profile modification WellOps MPG-19 01/Sep/2013 Static Pressure Survey [STA] Surveillance WellOps MPG-19 31/Aug/2013 Static Pressure Survey [STA] Surveillance "'CONT'D FROM 08-30-13 WSR***(wfr/sbhps)SET 3.5" WHIDDON @ 8238' SLMPULLED 1.5" P-15 XJR & SET 1.5" RK-DGLV IN ST#4 @ 7987' MDPULLED 1.5" P AWGRSL] MPG-19 31/Aug/2013 15 XJR FROM ST#2 @ 8165' MDRAN SBHPS AS PER PROGRAMSET RK-DGLV IN ST#2 @ 8165' MD PULLED RK-DGLV FROM ST#4 @ 7987' MD***CONT'D ON 09- 01-13 WSR**• Injection Profile modification AWGRSO MPG-19 30/Aug/2013 T/1/0=600/50/320 Assist S/L- displace tubing Rigged up to Pump -In -Sub and Performance enhancement pumped 75 bbls criesel down Tubing. FWHP=800/0/320 S-Line on location Clean tubing —WELL S/I ON ARRIVAL— (wfr/sbhps)RAN 3' x 1 7/8" WB & 2.80" G.RING DOWN TO 1100' SLM, SAW NO RESTRICTIONS.DRIFTED TBG W/ 2.70" x 20' DUMMY DRIFT TO 1100' SUM, SAW NO RESTRICTIONS. LRS DISPLACED TBG W/ 75 AWGRSD MPG-19 30/Aug/2013 BBLS OF CRIESELRAN 3' x 1 7/8" WB, 2.70" CENT & 2.50" LIB, TAGGED PRONG @ 8238' SLM.CURRENTLY RIH W/ 3 1/2" GS (half alm) & 3 1/2" WCS (oat=39").***CONT'D ON 08-31-13 WSR'** Pre-WL work T/I/0=1000/50/350 Freeze protect Tubing and Injeciton line. Pumped 22 bbls AWGRSU MPG-19 17/Dec/2012 60/40 down tubing, and 5 bbls neet meth down injection line. Final WHPs=1500/50/350 Freeze protection WellOps MPG-19 17/Dec/2012 Tubing Wash [TBW] Performance enhancement Clean tubing CONTINUED FROM 09-05-12 .** (c/o wfrv's)SET 1.5" P-15 XJR (345 AWGRSM MPG-19 06/Sep/2012 bwpd,16/64" light spring) IN ST#2 @ 8165' MD.PULLED 3.5" WHIDDON FROM 8220' SLM (empty).'** WELL LEFT S/I ON DEPARTURE "` profile modification WellOps MPG-19 06/Sep/2012 Gas Lift Valve Work [GLV] - Station 2 profile modification AWGRSM MPG-19 05/Sep/2012 T/1/0=350/0/200 Assist slickline. Pump 85 bbis 180 degrees criesel down tubing. Performance enhancement slickline on location at departure. Final WHPs=950/10/220 Clean tubing *** CONTINUED FROM 09-04-12 *** (c/o wfv's)LRS DISPLACED TBG W/ 85 BBLS OF CRIESEL.MADE SEVERAL RUNS W/ 10' x 2.25" DRIVE DOWN BAILER.BAILED FROM 8014' SLM TO 8222' SLM (tattle tail pin on shoe sheared).RAN 1.70" LIB TO AWGRSM MPG-19 05/Sep/2012 STA #4 @ 7987' MD TO VERIFY OPEN POCKET. RECOVERED OPEN POCKET IMPRESSION.SET 3.5" WHIDDON @ 8219' SLM.SET 1.5" P-15 XJR IN ST#4 @ 7987' MD (17/64",395 bwpd).PULLED 1.5" DGLV FROM ST#2 @ 8165' MD.RIH W/ KOT Performance enhancement & 1.5" P-15 FOR ST#2.**. CONTINUE ON 09-06-12 "' Clean tubing WELL S/I ON ARRIVAL `** (c/o wfrv's)RAN 2.66" CENT & 5' DRIVE BAILER.S/D AWGRO MPG-19 04/Sep/2012 @ 7985' SLM,WORKED DOWN TO 7997' SLM.RECOVERED SCHMOO IN BAILER.STBY FOR LRS.**" CONTINUE ON 09-05-12 *** Pre-WLwork T/I/O=510/0/200. ( FP TBG ) Pumped 25 bbls of 60/40 for TBG FP AWGRSM MPG-19 12/Jul/2012 FWHP=400/0/200. Swab, wing, SSV closed. Master, IA, & CIA open. Performance enhancement PT - pulsed CIA and OB zone for 5 hours respectively, no affect on MPG-16 OpHighlights© MPG-19 12/Jul/2012 observed Performance enhancement Attachment 3 1 of 5 MPG-19 Well History Source Well Date Description Purpose *** CONTINUED FROM 7-10-12 *** (c/o wfrv's)SET 1.5" DGLV IN ST#2 @ 8165' MD.PULLED 1.5" DGLV FROM ST#4 @ 7987' MD.PULLED 3.5" WHIDDON FROM AWGRSD MPG-19 11/Jul/2012 8222' SLM (empty).PERFORMED 5 HOUR INIECTIVITYTEST ON OPEN POCKET @ 7987' MD.R/D EQUIPMENT PER WS LEADER'**WELL INJECTING ON DEPARTURE*** Performance test *** CONTINUED FROM 7-9-12 *** (c/o wfrv's)MADE TWO BAILER RUNS W/ 10' X 2.25" DRIVE DOWN BAILER.BAILED FROM 8150' SLN TO 8222' SLM (tattle tail pin sheared on bailer shoe).SET 3.5" WHIDDON @ 8222' SLM.PULLED 1.5" P-15 XJR & AWGRSfI MPG-19 10/Jul/2012 SET 1.5" DGLV IN STA#4 @ 7987' MD.PULLED 1.5" P-15 XJR FROM STA#2 @ 8165' MD. PULLED 3.5" WHIDDON FROM 8222' SLM (empty). PERFORMED 5 HOUR INJECTIVITY TEST ON OPEN POCKET @ 8165' MD.SET 3.5" WHIDDON @ 8222' SLM.RIH W/ 3.5" KOT & 1.5" DGLV.*** CONTINUE ON 7-11-12 *** Clean tubing WellOps MPG-19 10/Jul/2012 Injectivity Test [INJ] Performance test *** WELL S/I ON ARRIVAL "' (c/o wfrv's)RAN 2.60" CENT W/ 2.25" LIB.S/D @ AWGRS[] MPG-19 09/Jul/2012 8154' SLM.RIH W/ 10' X 2.25" DRIVE DOWN BAILER.*** CONTINUE ON 7-10-12 * Clean tubing T/I/O = 500/0/192. Displacement for SL. Pumped 75bbls criesel down tubing. AWGRSD MPG-19 09/Jul/2012 FWHP's = 900/0/195 Swab, SSV, Wing = shut. Master, IA, CA = open Clean tubing *** WELL S/I ON ARRIVAL*** (c/o wfrv's)ATTEMPTED TO SET 3.5" WHIDDON.S/D @ 7974' SLM.UNABLE TO WORK,THRU,PULLING HEAVY OF BOTTOM THEN AWGRSD MPG-19 07/Jul/2012 CLEARS @ 7955' SLM.PUMP TRUCK UNAVAILABLE TO DISPALCE TBG.R/D FOR SCHEDULDED MAINT.RETURN ON LATER DAY.*** WELL LEFT S/1 ON DEPARTURE .* Clean tubing WellOps MPG-19 09/Dec/2011 Hot Oil Treatments [HOT] Clean tubing T/1/0= 850/40/200 temp= SI Freeze protect Rigged up to Injection line and pumped 5 bbls 60/40 meth. Rigged up to Tree cap and pumped 22 bbls AWGRST MPG-19 09/Dec/2011 60/40 meth to freeze protect. *'Swab, Wing, SSV= closed Master, IA, OA= open on departure** FWHP's=680/40/160 Valve testing T/1/O=1400/200/100 Freeze protect tubing and injection line. Pumped 22 bbls 60/40 down tubing and 3 bbls 60/40 down Flowline for freeze protect. **Swab, AWGRSD MPG-19 27/Oct/2011 Wing, SSV= closed. Master, IA, OA= open on departure*' FWHP's= 1000/200/100 Clean tubing T/1/0=1900/0/200 . Temp=110 RG-2401 (Surface casing corr. mitigation) PJSM. AWGRS MPG-19 15/Aug/2011 Strapped conductor @ 20". Install spill containment. Pumped 13.6 gal RG-2401 to fill conductor. RDMO. MANDREL HANGER W/FLUTE. Integrity *** CONTINUED FROM 5-17-11 *** (c/o wfrv's)R/D SLICKLINE EQUIPMENT.— AWGRSD MPG-19 18/May/2011 WELL LEFT S/I ON DEPARTURE * profile modification OpHighlights0 MPG-19 17/May/2011 WFV OA, OB open. CA 395, OB 345 profile modification WellOps MPG-19 17/May/2011 Gas Lift Valve Work [GLV] - Station 6,8 profile modification WellOps MPG-19 17/May/2011 Straddle Packer [STR] - @ 7751'-7960' profile modification *** CONTINUED FROM 5-16-11 *** (c/o wfrv's)SET 3.5" WHIDDON @ 8251' MD. PULLED 1.5" P-15 XJR (500 bwpd, 19/64" ports) & SET 1.5" DGLV IN ST#6 @ AWGRSM MPG-19 17/May/2011 7777' MD.PULLED 1.5" DGLV & SET NEW 1.5" DGLV IN ST# 8 @ 7571' MD.PULLED 3.5" WHIDDON FROM 8251' MD (empty).'** CONTINUE ON 5-18-11 *** profile modification T/1/O=1140/0/200 Assist S-Line (Displace Tbg). Pump 75 bbls Criesel down Tbg. AWGRS© MPG-19 16/May/2011 FWHP=1400/20/200. S-Line has control of well @ LRS departure. Clean tubing *** WELL INJ ON ARRIVAL*** (wfr c/o)DRIFT TO PRONG W/2.55" CENT, Tx 1- 7/8' stem, 2.80" CENT, 2.5" LIB. (clean imp of prong) S/D @ 8226' SLM ( poor jar AWGRS© MPG-19 16/May/2011 action ) LIGHT IMP OF PRONG. LRS DISPLACED TBG W/ 75 BOILS OF CRIESEL.RIH W/ 3.5" GS & 3.5" WHIDDON.-** CONTINUE ON 5-17-11 "' Clean tubing ***CONT'D FROM 5-8-11***(wfr c/o)WAITED FOR WELL TO STABILIZE, TOLD TO AWGRSD MPG-19 09/May/2011 R/D LRS WILL DO INJ TEST.WELL [NJ. ON DEPARTURE'**JOB COMPLETE*** WellOps MPG-19 09/May/2011 Injectivity Test [INJ) Performance test Attachment 3 2 of 5 • CJ MPG-19 Well History Source Well Date Description Purpose ***CONT'D FROM 5-7-11.** (wfr c/o)LRS DISPLACED TUBING W/ 75 BBLS OF CRIESEL.ATTEMPTED TO SET BABY WHIDDON ON PRONG @ 8251' MD.SET 3-1/2" BABY WHIDDEN ON PRONG @ 8,251' MD.PULLED P-15 XJR (200 bwpd) FROM ST #2 @ 8,165' MD.SET 1.5" RK P-15 XJR (345 bwpd, 16/64" ports, light spring) IN ST AWGRSO MPG-19 08/May/2011 #2 @ 8,251' MD.PULLED 1.5" RK P-15 XJR (400 bwpd) FROM ST #4 @ 7,987' MD.SET 1.5" RK P-15 XJR (395 bwpd, 17/64" ports, light spring) IN ST #4 @ 7,997' MD.PULLED 1.5" RK-DGLV FROM ST #6 @ 7,777' MD.SET 1.5" RK P-15 XJR (500 bwpd, 19/64" ports, light spring) IN 5T #6 @ 7,777' MD.BRING WELL ON INJ. FOR INJECTIVITY TEST, WAITING FOR WELLTO STABILIZE'*'CONT'D ON 5-9-11*** Clean tubing WellOps MPG-19 08/May/2011 AC -Load (LOD] FileDocuments MPG-19 08/May/2011 110508 MPG-19I P&R GL SHEET WellOps MPG-19 08/May/2011 Gas Lift Valve Work [GLV] - Station 2,4,6 WellOps MPG-19 08/May/2011 Straddle Packer [STR] - @ 7751'-7960' T/I/0= 400/20/200. Assist Slickine with Loading Tbg. Pumped 75 bbls criesel AWGRSN MPG-19 08/May/2011 down Tbg. FWHP= 1700/20/200. profile modification ."WELL INJ ON ARRIVAL*** (wfry c/o)DRIFT W/ 2.62" CENT, 3' x 1-7/8" stem, AWGR50 MPG-19 07/May/2011 2.80" CENT, 2.5" LIB TO PRONG @ 8,251' MD. (poor action, very light imp of prong).STANDBY FOR LRS***CONT'D ON 5-8-11*** profile modification " CONTINUED FROM 4-16-11 **' (i-prof)RAN PDS I -PROF AS PER AWGRA7 MPG-19 17/Apr/2011 PROCEDURE.RECOVERED GOOD DATA.*** WELL INJECTING ON DEPARTURE'** Pad Op Notified profile modification WellOps MPG-19 17/Apr/2011 Spinner/Temp/Pressure [STP] profile modification '* WELL INJECTING ON ARRIVAL** (i-prof) RAN 2.55" CENT, 3' X 1.875" STEM, AWGRSL>J MPG-19 16/Apr/2011 2.64" CENT & 2.5" LIB. S/D @ 8221' SLM. RECOVERED FAINT IMPRESSION OF PRONG.*** CONTINUE ON 4-17-11 *** profile modification WellOps MPG-19 16/Apr/2011 Spinner/Temp/Pressure [STP] profile modification WellOps MPG-19 30/Nov/2030 Straddle Packer [STR] - Set dummy @ 7571' MD @ 7552'-7751' profile modification OpHighlights0 MPG-19 30/Nov/2010 WFV OA,OB Open profile modification **" CONTINUED FROM 11-29-10 *"' (c/o wfrv's)SET 3.5" WHIDDON @ 8224' SLM.PULLED 1.5" WFRV & SET 1.5" DUMMY IN ST#8 @ 7571' MD.PULLED 3.5" AWGRSN MPG-19 30/Nov/2010 WHIDDON FROM 8220' SLM (empty).*** WELL S/I ON DEPARTURE""" Pad Op Notified profile modification WellOps MPG-19 30/Nov/2010 Gas Lift Valve Work [GLV] - Station 8 profile modification T/I/0=700/0/200 Assist S-Line Pumped 70 bbls 130* diesel down Tbg. DSO AWGRSO MPG-19 29/Nov/2010 notified SLB S-Line on well upon LRS departure. FWHP's=700/0/200 Clean tubing WellOps MPG-19 29/Nov/2010 Hot Oil Treatments [HOT] Clean tubing *** CONTINUED FROM 11-28-10 *** (c/o wfrv's)LRS DISPLACE TUBE W/ 70 BBLS OF 130' DIESEL.CONTINUE RIH W/ 2.65" CENT & 2.30" CENT.TOOLS STOPPED @ 8070' SLM.UNABLE TO GET ANY DEEPER.MADE SEVERAL RUNS W/ 2.65" CENT & 2.25" DRIVE DOWN BAILER.BAILED FROM 8070' SLM TO 8224' SUM. RECOVERED AWGRSM MPG-19 29/Nov/2010 THICK SCHMOO.RAN 2.60", Tx 1 7/8" STEM, 2.65" CENT, 2.30" LIB, S/D @ 8224' SLM.RECOVERED IMPRESSION OF PRONG.ATTEMPTED TO SET 3.5" WHIDDON,TOOLS STOPPED @ 8075' SLM.UNABLE TO WORK THRU.RAN 2.65" CENT,3' X 1.875" RLR,2.80" CENT & 2.30" LIB.TAGGED PRONG @ 8224' SLM.RECOVERED PRONG IMPRESSION.`"` CONTINUE ON 11-30-10 "' Clean tubing WELL INJ ON ARRIVAL'*' (c/o wfrv's) RAN 2.65" CENT & 2.30" LIB,TOOLS AWGRSCI MPG-19 28/Nov/2010 STOPPED @ 8000' SLM.UNABLE TO GET ANY DEEPER & PULLING HEAVY.LRS ENROUTE TO DISPLACE TBG.*`* CONTINUE ON 11-29-10 "" Pre-WL work WellOps MPG-19 15/Aug/2010 Spinner/Temp/Pressure [STP] Surveillance "**CONT FROM 08/14/10 WSR*'* (iprof)RAN PDS IPROF W/ SPINNER/T/P/X-Y AWGRSC! MPG-19 15/Aug/2010 CALIPER/GR/CCL, GOOD DATA"""WELL S/I ON DEPARTURE, PAD OP NOTIFIED'** Integrity '**WELL INJECTING ON ARRIVAL***(iprof)DRIFT W/ 2.70" CENTRALIZER, 3' 1- 7/8'. STEM, 2.50" SWAGE, 2.25" LIB, SD @ 8214' SUM, ACQUIRE GOOD AWGRSO MPG-19 14/Aug/2010 IMPRESSION OF PRONGBEGIN LOGGING W/ PDS I -PROF STRING AS PER PDS LOGGING PROCEDURE"**CONT ON 08/15/10""' Performance test STP (PROF - Log had no value. 60 fpm up goes to zero (both in -line and spinner) after N sand, 90 & 120 fpm get extremely erratic and nothing can be determined OpHighlightsr9 MPG-19 14/Aug/2010 below N. Stop counts were not presented because of "shoo-in well make stop counts invalid". Surveillance Attachment 3 3 of 5 0 u MPG-19 Well History Source Well Date Description Purpose T/1/0= 450/80/200 Temp= S/I Assist wireline pump as directed- Pumped 20 AWGRSD MPG-19 07/Jul/2010 bbls 60/40 MW down the tubing. Final WHP's= 450/80/200 "Slickline has control of well at departure" Clean tubing **'WSR Continued from 07-06-10"** Temp= SI Assist Slickline pump as directed AWGRSR1 MPG-19 07/Jul/2010 Pumped 34 bbls 50/50 crude/diesel mix down TBG, Final WHP's 800/100/200 "SSL on well @ departure" Clean tubing `"* CONTINUED FROM 07-06-10 **' (c/o wfrv's ) SET 1.5" P-15/XJR (400 bwpd,17/64" light spring) IN ST# 4 @ 7987' MDPULL P-15 & SET NEW 1.5" P- AWGRShI MPG-19 07/Jul/2010 15/XJR (400 bwpd,17/64" light spring) IN ST#8 @ 7571' MD.RAN 1.70" LIB TO ST#8,4 & 2 TO VERIFY P-15'S SET IN MANDRELS.RECOVERED LATCH IMPRESSION IN ALL STATIONS.'"' WELL LEFT S/I ON DEPARTURE `"' profile modification MPG-19 07/Jul/2010 WFV NB, OA, OB open (same vols as 4/14/2010) Valve testing MPG-19 07/Jul/2010 Gas Lift Valve Work [GLV] - Station 2,4,8 profile modification rAWGRSM T/1/0= 760/60/200 Temp= SI Assist Slickline pump as directed- Pumped 1 bbl MPG-19 06/Jul/2010 neat methanol spear followed with 9 bbls 50/50 diesel crude mix, SSL RIH ----- Job In Progress----- *"WSR Continued on 07-07-10*** Clean tubing '* CONTINUED FROM 07-05-10 **' (c/o wfrv's)PULLED 1.5" P-15 FROM ST# 4 @° 7987 MD.ATTEMPTED SET 1.5" P-15 IN ST#4 @ 7987' MD.TOOLS SLOWED @ AWGRSN MPG-19 06/Jul/2010 7550' LSM,WORKED DOWN TO 7700' SLM.PULUNG HEAVY OFF BOTTOM.STBY FOR LRS TO DISPLACE TBG.'*' CONTINUE ON 07-07-10 **' profile modification T/1/0= 700/60/200. Assist Slickline. Pumped 45 bbls criesel down Tbg while AWGRSD MPG-19 05/lul/2010 Slickline worked. FWHP= 1900/60/200. Clean tubing ***CONT'D FROM 07-06-10*'*(wfr c/o)ATTEMPTED TO SET 1.5" RK P-15 (12/64" port, light spring, 200 bwpd) IN ST #2 @ 8165' MD.LRS PUMPED @ 1 BPM, WHILE AWGRSD MPG-19 05/Jul/2010 SETTING VALVE. TOTAL OF 46 BBLS OF CRIESEL WAS PUMPED.SET 1.5" RK P-15 (12/64" port, light spring, 200 bwpd) IN ST #2 @ 8165' MD.*** CONTINUE ON 07- 06 10 **' profile modification **'WELLS/I ON ARRIVAL"`(wfr c/o)WLV FUNCTION TEST (good) WITNESSED BY ADW WSL JOHN PERLRAN 2.60" cent, 3' x 1-7/8" stem, 2.70" cent, 2.30 LIB. SD AWGRSN MPG-19 04/Jul/2010 @ 8,219' SLM. REC CLEAN IMP OF PRONG.PULLED 1.5" P-15 WFRV FROM ST #2 @ 8,165' MD.ATTEMPTED TWICE TO SET 1.5" RK P-15 XJR (12/64" port, light spring, 200 bpd) IN ST #2 @ 8,165' MD.'**CONT'D ON 07-05-10'** Valve testing T/1/0= 1200/220/220. Hot tubing. Pumped 75bbls Crude/Diesel (50%/50%) AWGRSD MPG-19 03/Jul/2010 down tubing. FWHP's = 500/160/200. Swab, Wing, Choke= shut. Master, SSV, IA, CIA = open. Clean tubing WellOps MPG-19 03/Jul/2010 Hot Oil Treatments [HOT] Clean tubing T/I/0250/250/250 Bleed CIA from 250 to 100psi also bumped up the IA with N2 AWGRSD MPG-19 10/Jun/2010 from 250 psi to 480 ending T/I/O 250/480/100 performance enhancement WellOps MPG-19 10/Jun/2010 Annular Communication Work [ANN] Integrity T/1/0=800/250/0 Injectivity Test Pumped 9.5 bbls diesel down Tbg to obtain AWGRSCM MPG-19 14/Apr/2010 injectivity, of 0.65 bpm @ 1350 psi & 1 bpm @ 1900 psi. DSO notified SUB S-Line on well upon LRS departure. FWHP's=1100/250/0 Surveillance **' CONTINUED FROM 04-13-10 "'RIH W/ 3.5" OM-1 W/ 1.625" 1DS.UNABLE TO GET TO ST#2,S/D @ 8022' SLM.PUH & PULLED 1.5" WFR FROM ST#4 @ 7987' MD.SET 1.5" DGLV IN ST#4 @ 7987' MD.LRS PUMPED 2 BBLS OF DIESEL.TBG PRESSURE BUILT UP TO 2500 PSI.LRS PUMPED 5 BBLS OF DIESEL THRU WFR IN AWGRSO MPG-19 14/Apr/2010 ST#2 @ 8165' MD.PULL DUMMY/SET 1.5" RK P-15 XJR ( 12/64, 200bpd, light spring) STA# 2 @ 8165' MD.PULL DUMMY/SET 1.5" RK P-15 XJR ( 17/64, 400bpd, light spring) STA# 4 @ 7987' MD.PULL DUMMY/SET 1.5" RK P15, ( 17/64, 400bpd, light spring) STA# 8 @ 7571' MD.LRS PERFORMED INJECTION TEST.GOOD TEST.'"' WELL LEFT S/I ON DEPARTURE *'" profile modification WellOps MPG-19 14/Apr/2010 InjectivityTest [INJ] Surveillance *"'Job In Progress Continued From WSR 04-13-10— Assist S-line Pumped 7 bbls AWGRS© MPG-19 14/Apr/2010 diesel down Tbg. DSO notified SUB S-Line on well upon LRS departure. F W H P's=1250/250/0 Surveillance OpHighlights� MPG-19 14/Apr/2010 WFV NB, CIA, OB open Valve testing T/I/0= 500/250/40 Assist 5-Line Pumped 20 bbls diesel down Tbg. ***Job In AWGRS© MPG-19 13/Apr/2010 Progress Continued On WSR 04-14-10— lClean tubing Attachment 3 4 of 5 • E MPG-19 Well History Source Well Date Description Purpose "* CONTINUED FROM 04-12-10 ***MAKE SEVERAL RUNS W/ 2.63" CENTS' X 2.25" D/D BAILER (mule flapper shoe). FROM 8001' TO 8010' SLM. RECOVER 2.5 GALLONS SCHMOOLRS PUMP 10 BBLS DIESEL.RUN 2.63" CENT, 3 x 1 7/8" STEM, 2.25" LIB S/D @ 8020' SUM, NO IMPRESSIONRUN KJ, 2.54" CENT, 5' x 1 7/8" AWGRSPI MPG-19 13/Apr/2010 STEM, 2.63" CENT, 3' x 1 7/8" STEM, 2.25" LIB.S/D @ 8028' SLM,NO IMPRESSIONPULL 1.5 WFR & SET 1.5" DGLV IN STH8 @ 7571' MD.LRS PUMPED ANOTHER 10 BBLS OF DIESEL.TBG PRESSURE BUILT UP TO 1100 PSI.RIH & LIB ST#8 @ 7571' SLM.IMPRESSION OF LATCH.RIH W/ 3.5" OM-1 W/ 1.625" JDS.*"* CONTINUE ON 04-14-10 *** profile modification WellOps MPG-19 13/Apr/2010 Straddle Packer [STRI - Set dummy @ 7571' MD @ 7552'-7751' profile modification WellOps MPG-19 13/Apr/2010 Gas Lift Valve Work [GLVI - Station 8 profile modification T/l/0= 1000/40/250. Assist slickline with load Tbg. Pumped 80 bbls 130* diesel AWGRSPI MPG-19 12/Apr/2010 down Tbg. FWHP= 1000/40/250. Clean tubing *** WELL INJECTING ON ARRIVAL *** (c/o wfrv's)LRS DISPLACED TBG W/ 80 BBLS OF HOT DIESEL.RIH W/ 2.63" CENT& 2.25" UB,S/D @ 7990' SLM.WORKED DOWN AWGRSbI MPG-19 12/Apr/2010 TO 8000' SLM.WEIGHT DROPS DOWN FROM 750 LBS TO 450 LBS WHEN PULLING OUT@ 7980' SLM.*** CONTINUE ON 04-13-10 *** Clean tubing ***Job In Progress Continued From WSR 01-26-10*"* Red Dye Test Pumped 3 AWGRSI?I MPG-19 27/Jan/2010 bbls pw/dye mix & 3 bbls neat methanol down Tbg. DSO notified swab shut, wing ssv master is oa open. FWHP's=1000/0/200 Surveillance T/1/O=1000/450/250 Red Dye Test Pumped 3 bbls neat methanol & 40 bbls AWGRSN MPG-19 26/Jan/2010 pw/dye mix down Tbg. ***Job In Progress Continued On WSR 01-27-10*** Surveillance T/1/0 = 500/0/250 Red Dye Test. Pumped lbbls 60/40, 41.5bbis red dye AWGRSU MPG-19 19/Dec/2009 mixture, 4.5bbls 60/40 down tubing. FWHP's = 1000/0/250. DSO to bring online when testers are ready. Swab, Wing = shut. Master, SSV, IA, OA = open. Surveillance T/1/O=770/50/250. (State witness MIT IA/ State rep -Bob Noble) MIT IA to 2000 AWGRS[fl MPG-19 17/Mar/2009 psi. Passed. IA lost 80 psi in first 15 minutes & 10 psi in second 15 minutes. Total loss=90 psi. Bleed IA pressure down to 200 psi. FWHP=770/200/250. Integrity Attachment 3 5 of 5 0 0 Attachment 5: MIT Tracking System Documentation of Well Status: The following diagram summarizes the responsibilities defined in Well Integrity Operating Policy (WIOP) for BPXA. Well integrity management has cross functional responsibilities between Reservoir Development, Wells, and Operations: Management of Not -Operable Wells In;hat ll repo emtor nterven Reservoir T Development iWell Repaired and Integrity Change j Retum Well E-mail Tested E-mail well status Yes to Operable in Notification: —�� ( Notification: to. AnnComm AOGCC I AOGCC Well Integrity dentify En aluation' AHeded Parties 1, Affected Parties Well IS WeII Change Status AnnComm Change status AnnComm Eng/Coordinator Anomally AnnComm Operabe o"Not updatesDB: to"Operable" and initiate updates Da: and report No Operable"in 1.DWF in AnnComm 1.DWF A to WIC Diagnostics AnnComm Starts 28 2. Automation 2. Automation 3, AM Reports 3. AM Reports day clock New Step IOn eck Operations locks Appliwhons out WV and before Bnng Well Operations installs"NO"sign Online Monitorwell TlOdata Dailyand record into operator Tools Documentation of MIT Tracking System How Data is Managed: Below is a screen shot of the AnnComm Application. This application records the required MIT test frequency with a default of 48 months (4 years), the historical test dates, and test results. AnnComm System .... �.-T...r. .. F,le Pmmts H&Aul i elks L%6b s I-". s:ea 01 - - --- _ Wd.K— MPE MPS W MPG01 MPG-13 wen MPG-19 13 ld 'O7 15 A END] ACaI EN02 8 EN03 GM LS H LGI MI'F N W MPG-02 MPG-td I LPC �NGI W MPG-03 MPG-15 Wl Stator �Opeabk - - __ 1 Saye W ifi 81 ENCa J M MPH NIK?/Tt NP MPG-0t MPG-/6 Wei Type (Pwl `-- ___ `OS 1? BSRT ENDS K Pig Mrl NK W,MPGAS MPG-1? 1— o- 06 to C F L WA MP., NP=aLE NP.. .1i MPG-19 --� a? I8 CC G iPK L] MPB lW-MS NS iMF1i 89 IE CD3 GL'-1 U MPC MPL wa;c WMPGaJ v 2F D Gc-Z u MP1:FP ii NPCI E Div MP6-10 12 2X E tit:-:i Ld MPD 1NM MP$iD tRn'MPG-'il T,en SSW 91" PmLYsI -_ stare Pmraed A6tn Wl Note: L50 @8251'm OlAiN5lar PWI aeLfv, ` > 01,111M Mat @ a251-firkalk DaY: Gvw !A.vbx1 >avlaAW R ms gr�ymz518�.t+rwa GATT p A 4v 21117i) d.A A PEJOR 0 OA(8) 11YA > 0 V241n.. Set WFRa in 5r6 NZ14 >Qi/'Lrvl)9� .A t18 area MPG-19 ODA Al :YN) >OJYI7f09. amedW PTO 201192il OOOA{Y>) il Wal EvMx1Tq DaNa PMt�Prod/kj RoI' qW SLWx t PkiAaa 1 PE kfo 0-ft—_'iVLLa Datre Text PneRod Ewa"Typ. Cansna4 Pnr E. Pa Mail Obswfiyn:AAi!iu^Mrvralmmwlu '3`.D2017 L )00 Y .. Y MITA W nys by ADGCC Ray Ck.* So--. Tat Data MIT -TOWN Well MPG 19 q?r20l3 N MfT4'. MITU7LlAT 18 PTO: 1tA74.192U 1 I?:2pY3 eU)U Y Y MITA A1NiCS; w. Illy NoHa Add f , T MUT40A _ Lit AOGC: MITIA on 9flf2013 b't.L'e'd75 Z5 t0 Y Y META gvG,y MITI;.:^Ftraxxirr ws.^ea br ;eR la'»s LW,ryryyd AA CHIT tM dale1TJoanot w ,iday a TIfL mxeh without WIC NFT aPP"'v'i7 PMT A FL Padcw Depth OA FL 4196 TVD. R Inspection %k S-d�y> 9ont1i1, AOGCC i q Rpt> I 7545 MO, Ft 00- O:laftev A�O:,CC lq Rid Attachment 5: MIT Tracking System How Testing Dates are Managed: Data from the AnnComm database is used to manage MIT testing schedules. Well classification is also recorded in the automation system for the DSO or Board Operator to filter wells available to produce. The well status from AnnComm is automatically distributed to other systems daily at a defined frequency. These system are available to Operators, Well Engineers, and Pad Engineers to clearly understand current well status: 1. The Automation System: See comment of "N" or "O" next to the well on a well status report. These can be generated by FS or DS level. This may be the easiest method to tell if a shut-in well is Operable or Not Operable. 2. Digital Well File (DWF): This application resides on the internet and is available for all disciplines. This takes some time, but the pad operator or board man will need to open DWF and go to the Well Integrity tab. Example below: digital well 1 i I e (; I. t5 ® r❑ ❑( 0 ALASKA / ALASKA CONSOLIDATED TEA" / END / 1 / 1-15 -"S ❑> I�""'a 1�I1 ^e" "�•`1 Well Integ Opel• Notes LAnnu as_ress uPa . ys tt g NDfspewsstions Awotwalies Casjn9 latlw9s TIveshelds Teee "aiwtenewce Departures Reports Oleeds CadiPtxs "elp WI Info >> Hume 'TTP seat 11 t2200' MO - LVJ/20i l0 —_—� > 081 L6101: LOL toting W.k 011,858' 'NOTE: W111 require AOGCC MR-U once rxpairad :LOL Iaund leak at I1687' - I0J311 t0 :MR-U Failr l - W/LVIO Parker-,im—nd - 09/31ll til :Unable ko pull pab:h - t LI Z3/ 10 Slaw 1A repn_ —4— 741 pab:h —A L L847 L L367' nrpair lr11A'"men 05% 31/ O3 10-K TREE, Casing Valves a e 2 1116 in, 8XA 152 Ring, DSM has two new Integrals available zsoo LOGO 500 500 :ITp pab:h PC leak, CA > O1/05f02: Ran nip red—, set TTP CR ss -> 01J29J03: M-TxIA Paed3000pn 4J - > 01-31"t CMTT TxU Passed 2500Psi 61 05J3t/D4: Tbg PiichLt I1847'- I t867' -> 0t7/04: MITLA Passed to 4000 psi > OWIW 04: AOGCC MRIA Passed to 4000 psi > Ot)20+'06: NPOfrd AOGCC of slow IA repressu rzation, plan to leave on in3action for HMA 6211 U06: AOGCC NRIA Passed to 4000 psio left lanes > 07fr 77rM: Finaa bn Winton A Jim natifNlna plans • ...... t-t5/P-25 93 7 veL 3. Morning reports: Morning reports are automatically distributed and tell the receiver what well status changes occurred in the last 24 hours. Morning Reports automatically Communicate the following information: Well Integrity Diagnostics Report (Well Integrity Engineer and Coordinator) • Not Operable Wells showing to be on line (typically triggered by an open IGV) • Wells Under Evaluation with TIO's and forward plan • Attachment 5: MIT Tracking System • Injection Diagnostics Report (Well Integrity Engineer and Coordinator) • Wells on line with MIT's due in the next 30 days, and 30 to 90 days Area Managers Report (Field Operations, Well Integrity) MIT's due in the next 30 days and 30 to 90 days for wells on line Not Operable Wells showing to be on line (typically triggered by an open IGV) Wells that have had a WI status change in the last 24 hours Attachment 6 Summary of Management of Change Management of Change Number: AMOC-All Alaska-1483 Responsible Organization: BPXA Operations Short Description: Revision to WIOP for "Not Operable" well requirements Description of Change: Under the Well Integrity Operating Practice (WIOP), an injection well that lacks a current mechanical integrity test must be shut in and classified "Not Operable." Under this MoC, WIOP will be updated to require that wells that are classified as "Not Operable" and under Operation control shall be locked to prohibit operation of the flowline wing valve and tagged "Non -Operable Well." The Field/Facility Operations Team Lead or designee shall retain possession of the lock's key in a secure area and shall make it available during permitted well work -over and maintenance activities. Change Initiated by: Operations Full Field Onshore Site Manager, 9/27/13 Reviewed by: Wells Integrity Team Leader Operations Full Field Onshore Site Manager Reservoir Development Fieldwide Team Leader Authorization of Change: BPXA Operations VP Implementation: Immediate Communication: All North Slope facility Offshore Installation Managers and Site Managers THE STATE Alaska Oil and, Gas 01A L A S K--A- Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 September 24, 2013 Certified Return Receipt 7009 2250 0004 3911 5891 Mr. Ryan Daniel Alaska Region Wells Integrity and Compliance BP Exploration Alaska, Inc. 900 E. Benson Blvd Anchorage, AK 99501 Re: Investigation of missed MIT of MPU MPG-19 (PTD 2041920) Area Injection Order IOB Milne Point Field Dear Mr. Daniel: On September 5, 2013 Randy Redmond, Operations Full Field OSM, with BP Exploration Alaska, Inc (BPXA) contacted the Alaska Oil and Gas Conservation Commission (AOGCC) by telephone and subsequent email to report that well MPG-19 was brought back on line for approximately two days before BPXA discovered the well was operating without a current Mechanical Integrity Test (MIT) and shut it in. The email states that a MIT is being coordinated with the AOGCC site inspectors, and that BPXA has taken immediate action in initiating personnel progressive disciplinary action in not following procedures and practices, and to roll out additional training to clarify roles and responsibilities that ensure well status is verified and validated prior to flowing a well to prevent a re -occurrence. Pursuant to 20 AAC 25.300, within 30 days of the date this request is sent, the AOGCC requests the following additional information be provided: 1. Current wellbore schematic; 2. TIO plot and raw data for last 90 days; 3. Well history and timeline detailing work completed since last MIT dated 3/17/2009; 4. documentation of the completed BPXA incident review, specifically to verify that the investigation was broadened to review and identify all similar potential missed MIT scenarios across BPXA facilities; Investigation of missed MIT M10MPG-19 • September 24, 2013 Page 2 of 2 5. documentation on the BPXA MIT tracking system, procedures and practices, for determining when MIT's are required, including the contingencies for wells shut in at the time an MIT is due and its procedures for notification to the AOGCC, as well as it's procedures for determining the MIT due date and identification of past due wells; 6. proof or schedule detailing additional training (sign off sheets or affidavits); 7. documentation showing that BPXA has broadcast this incident and findings internally with the aim of increasing awareness and sharing the lessons learned. The AOGCC reserves the right to pursue enforcement action in connection with this investigation of well MPG-19 as provided by 20 AAC 25.535. Sincerely, Cathy P. oerster Chair, Commissioner cc: Thor Cutler, USEPA, Region 10 AOGCC Inspectors RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed, If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t)he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m on the next day that does not fall on a weekend or state holiday. • Colombie, Jody J (DOA) From: Wallace, Chris D (DOA) Sent: Monday, September 23, 2013 12:07 PM To: Colombie, Jody J (DOA) Subject: FW: MPG-19 Op w/o Current MIT Attachments: BPXA_MPU_MPG-19_investigation_request_missed_MIT_injection.docx Jody, Please review and if all OK present for commissioner signature. Please add to the compliance calendar once we get a date established. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 71h Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.gov From: Wallace, Chris D (DOA) Sent: Thursday, September 12, 2013 12:19 PM To: Regg, James B (DOA) Subject: RE: MPG-19 Op w/o Current MIT Please review. 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 From: Regg, James B (DOA) Sent: Monday, September 09, 2013 10:26 AM To: Wallace, Chris D (DOA) Subject: FW: MPG-19 Op w/o Current MIT Satisfied with this approach or should we do something more formal? aim Rugg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 'crom: Redmond, Randy [mailto:RedmonRF(a>BP.com] Sent: Thursday, September 05, 2013 5:47 PM To: Regg, James B (DOA) Cc: Price, Bruce; AK, CPS MPU OSM; AK, CPS MPU Field Ops TL; Daniel, Ryan; Youngmun, Greg L; Williams, Bruce J; AK, OPS FF Well Ops Comp Rep; O'Riordan, Colm J; Kiorpes, Steve T Subject: MPG-19 Op w/o Current MIT Dear Mr. Regg, As a follow up to my voice mail message today; On September 3rd of this year BPXA had discovered and shut in Milne Point Unit (MPU) Produced Water Injection Well, MPG-19, operating at minimum flow of 200-250 BPD with a WHIP of approximately 800 psig. This incident occurred as a result of misunderstanding of well status during a well work hand over. Wells Slickline began and completed well work activity during the period of August 30 to September 1S' of this year. Operations received the well but did not understand that it was classified as "not operable" based on a non- current mechanical integrity test (MIT), ref. 20 AAC 25.402(e) and 25.412(c), and began flowing the well at minimum rate and pressure for a period of approximately two days prior to discovery. An MIT is being coordinated with the AOGCC Site Inspectors for the current month. BPXA has taken immediate action in initiating personnel progressive disciplinary action in not following procedures and practices, and to roll out additional training to clarify roles and responsibilities that ensure well status is verified and validated prior to flowing a well to prevent a re -occurrence. 'f you have any questions, please contact me 907-564-4889. Sincerely, Randy Redmond Randy Redmond, PE BPXA, Operations Full Field OSM RedmonRF(cD_BP.com 907-564-4889 cell 907-529-2689