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CO 202
Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~~, Order File Identifier Organizing (done) RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: Maria ~ Production Scanning x30= Date: `~ ~ ~ ~ / ~~=~z~~e.dea iiiumiuiuiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: '` _ ~~P ,,~~~~~~~~~~~~u~uurv~ f + =TOTAL PAGES-s~~~"% (Count does not include cover sheet) / /s/ Stage 7 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date:~~ / ~~"/ ~ f~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II~I~I VIII II II~ ReScanned I)I (III'I ((III I) IIf BY: Maria Date: Comments about this file: ~wo-sided ~~~ ~~~~~~ ~~ ~~~ ~~ ~~~ DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date: ~' l ~ Date: ~~/ ~ (~ I o;a~~.~~e~.ed uiiiuiilliNmu 10/6/2005 Orders File Cover Page.doc • • Index Conservation Order 202 Endicott Field 1. August 12, 1988 Standard Alaska Production Company's request to Gas Vent or Flare 2. May 8, 1989 BP Exploration ltr re: RFT Pressure Measurement Inclusion on Endicott Field Rule 6e 3. March 2, 1990 BP Exploration re: Administrative Approval for exception to Rule 3 (CO 202.06) 4. May 21, 1990 BP Exploration re: Administrative Approval for exception to Rule 3 (CO 202.07) 5. July 16, 1990 BP Exploration re: Administrative Approval for gas flaring 6. October 24, 1990 BP Exploration re: Administrative Approval for exception to Rule 3 7. October 30, 1990 BP Exploration re: Administrative Approval for gas flaring 8. December 31, 1990 BP Exploration re: Administrative Approval for exception to Rule 3 9. January 21, 1991 BP Exploration re: Administrative Approval for gas flaring 10. Apri122, 1991 BP Exploration re: Administrative Approval for gas flaring 1 1. October 7, 1991 BP Exploration re: Administrative Approval for exception to Rule 3 12. October 11, 1991 BP Exploration re: Administrative Approval for gas flaring 13. February 18, 1992 BP Exploration re: Administrative Approval for gas flaring 14. April 1, 1992 BP Exploration re: Administrative Approval for gas flaring 15. May 18, 1992 BP Exploration re: Administrative Approval for gas flaring 16. July 10, 1992 BP Exploration re: Administrative Approval for gas flaring 17. October 21, 1992 BP Exploration ltr providing the results of the Key Well GOC Monitoring Program 18. November 5, 1992 BP Exploration re: Administrative Approval for exception to Rule 3 19. November 12, 1992 BP Exploration ltr re: placement criteria for J-33 20. December 16, 1992 BP Exploration request for Safety Flare Volume 21. December 31, 1992 BP Exploration request to Extend the provision of CO 202-15 until permanent pilot gas volumes are assigned 22. January 12, 1993 BP Exploration re: Administrative Approval for gas flaring • • 23. February 4, 1993 BP Exploration re: Administrative Approval for gas flaring 24. February 24, 1993 BP Exploration re: Administrative Approval for gas flaring 25. March 4, 1993 BP Exploration re: Administrative Approval for gas flaring (CO 202-21) 26. March 22, 1993 BP Exploration re: Administrative Approval for gas flaring 27. March 24, 1993 BP Exploration re: Administrative Approval for gas flaring 28. May 4, 1993 BP Exploration re: Administrative Approval for gas flaring 29. June 17, 1993 BP Exploration re: Administrative Approval for gas flaring 30. June 24, 1993 BP Exploration re: Administrative Approval for gas flaring (CO 202-26) 31. July 8, 1993 BP Exploration re: Administrative Approval for gas flaring (CO 202-27) 32. September 17, 1993 BP Exploration re: Administrative Approval for gas flaring (CO 202-28) 33. October 19, 1993 BP Exploration re: Administrative Approval for gas flaring (CO 202-29) 34. February 3, 1994 BP Exploration re: Administrative Approval for gas flaring (CO 202-30) 35. February 21, 1994 BP Exploration re: Administrative Approval for gas flaring (CO 202-31) 36. February 23, 1994 BP Exploration re: Administrative Approval for gas flaring (CO 202-32) 37. March 25, 1994 BP Exploration re: Administrative Approval for gas flaring (CO 202-33) 38. June 3, 1994 BP Exploration re: Administrative Approval for gas flaring (CO 202-34) 39. June 17, 1994 BP Exploration re: Administrative Approval for gas flaring (CO 202-35) 40. November 28, 1994 BP Exploration re: Administrative Approval for gas flaring (CO 202-36) 41. December 18, 1995 BP Exploration request for spacing variance 1-59/0-24 42. May 3, 1996 BP Exploration Reservoir Surveillance Report 1995 43. June 26, 1998 BP Exploration Petition for Amendment 44. June 26, 1998 Notice of Hearing and Affidavit of Publication 45. July 11, 1998 Corrected Notice of Hearing and Affidavit of Publication 46. August 6, 1998 DIU Meeting 47. January 25, 2001 BP Exploration proposed spacing variance 2-28a/0-19 48. February 19, 2003 BP Exploration proposed spacing variance 4-10/L-28 49. February 19, 2003 BP Exploration proposed spacing variance 3-17E/K-30 • • 50 51 March 10, 2003 BP Exploration proposed spacing variance 2-28B/0-19 November 20, 2008 BP Exploration request for surface Commingling of Production for We112-30B/ME-O1 (CO 202-043) Conservation Order 202 ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 Re: THE REQUEST OF SOHIO ) Conservation Order No. 202 ALASKA PETROLEUM COMPANY to ) present testimony to deter- ) Endicott Field mine pool rules for the ) .Endicott Oil Pool Endicott Oil Pool. ) September ?_0, 1984 IT APPEARING THAT: 1. Sohio Alaska Petroleum Company requested the Alaska Oil and Gas Conservation Commission to hold a public hearing in order to receive testimony for the establishment of pool rules f_or the development and exploitation of the Endicott Oil Pool. 2. Notice of the public hearing was published in the Anchorage Times or_ July ?_4, 1984 and in the Anchorage Daily News on July 25, 1984. 3. A public hearing was held in Anchorage Assembly Room, 3500 Alaska on August 22, 1984. the Municipality of Fast Tudor Road, Anchorage, 4. Members of the staff of Sohio Alaska Petroleum Company presented testimony and the hearing record was closed at the end of the public hearing. FINDINGS: 1. Hydrocarbons are trapped in the Kekiktuk Formation, a part of the Endicott Group. 2. There has been widespread usage of "Endicott" as th.e field name and the field anal pool should be named Endicott Field and the Endicott Oil Pool. 3. The vertical limits of the pool may be defined by the accumulations in the Sohio A1_aska Petroleum Company Sag Delta No. 4 well which appears to be a typical and representati~~e well. 4. Well control and structural interpretation are adequate to reasonably define the areal limits of the accumula- tion. Conservation Oho. 202 Page 2 September 20, 1984 5. The pool is bounded by several major faults and there appear to be numerous minor faults within the field limits. 6. The areal extent of the hydrocarbon-bearing reservoir is about 8600 acres. 7. A gas-oil contact has been determined to be a planar horizontal surface fieldwide at 9855 feet subsea. 8. The oil-water contact is assumed to be a planar hori- zontal surface fieldwide at 10,192 feet subsea. 9. A spacing pattern denser than one well per 160 acres may be necessary to recover the maximum amount of oil. 10. The field is characterized by faulted structural patterns, inconsistent lithology and changing lateral and vertical reservoir characteristics. 11. To adequately evaluate the effectiveness of the reservoir depletion plan, the reservoir pressure, the gas-oil ratio, the gas-oil contact, and the productivity profile of wells should be monitored on a regular and continuous basis soon after regular production commences. 1?_. Enhanced recovery methods must be employed to achieve maximum recovery. Studies have indicated that a full field waterflood project started within two years after initial production will greatly increase recovery and will not preclude other additional enhanced recovery projects in the future. 13. Studies indicate the ultimate recovery from the reservoir is sensitive to the daily offtake rate. 14. All wells will be drilled from man-made gravel islands with a surface grade approximately 22 feet above the original mud line or ocean floor. 15 The contribution of intervals open to the wellbore in each producing well may be determined by running produc- tivity profile surveys. 16. Initial reservoir and bubble point pressures are estimated to average 4840 psig. The reservoir tempera- ture ranges from 200 to 225 degrees Fahrenheit. 17. Studies indicate that all produced gas, excepting volumes used for lease purposes, should be injected into the gas cap to assist in reservoir pressure maintenance. Conservation Page 3 Se tem r p be 20, Oro . 202 1984 18. Structural casing set the mud line appears operations. t through the island gravel and below necessary to conduct wellbore 19. Conductor casing set and cemented a minimum of 75 feet below the island surface should provide adequate anchor- age for a diverter system. 20. The effects of permafrost thaw-subsidence and freeze back loadings can be mitigated by setting and cementing surface casing of sufficient strength at least 500 feet below the base of the permafrost but no more than 2700 feet true vertical depth. 21. Several casing types and grades that are approved for use as surface casing in the Prudhoe Bay Field and the Kuparuk River Field are adequate for this field. 22. Perforation of cemented casing or liners, slotted liners, wire wrapped screen liners, and open hole completions appear to be equally effective completion techniques. 23. Unless the pool is operated under a unit agreement, the pool management program contemplated in the testimony can not be undertaken, without negatively impacting correla- tive rights. 24. Statewide regulations presently in effect govern field operations except as modified by this conservation order. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth apply to the following described area referred to in this order as the affected area: UMIAT MERIDIAN T11N R16E Sections 1, 2, and 12. T11N R17E Sections 3, 4, 5, 6, 7, 8, 9, 10, 13, 14, 15, 16, and 17. T12N R16E Sections 25, 26, 27, 34, 35, and 36. That portion of those lands in the S2 S2f NW4 of Block 653 lying north of the south boundary of Sections 2.2, 23, and 24; T12N, R16E, U.M., Alaska (being identical with line 6-7 on Block 653) and those lands in the SZ SW4 NE4 of Block 653 lying north of the south boundary of Section 24, T12N, R16E, U.M., Alaska and east of the west boundary of Section 30, T12N, R17E, U.M., Alaska and those lands in the SW4 SE4 NE4 of Block 653 and those lands in the SE4 of Block 653 lying east of the west boundary of Sections 30 and 31, T12N, R17E, U.M., Alaska and those lands in the SW4 SW4 of Block 654 and Conservation Oro. 202 Page 4 September 20, 1984 those lands in the SW4 NW4 SW4 of Block 654 and those lands in the SW4 SE4 SW4 of Block 654 and those lands in Block 697 lying in T12N, R17E, U.M., Alaska being the northeast portion of Block 697 and those lands in the NW4 of Block 698 lying north of the south boundary of Sections 31, 32, and 33, T12N, R17E, U.M., Alaska and those lands in NW4 NW4 NE4 of Block 698 lying north of the south boundary of Sections 33 and 34, T12N, R17E, U.M., Alaska which are within the offshore three-mile arc lines and which are all listed as state area on the "Supplemental Official O.C.S. Block Diagram" approved October 19, 1979 and December 9, 1979, respectively. That portion of those lands in the S~ and S2 NZ of Block 698 lying east of the west boundary of Sections 2 and 11, T11N, R17E, U.M., Alaska (being identical with the line 4-5 Block 698) and lying north of the south boundary of Section 11, T11N, R17E, U,M,, Alaska (being identical with line 5-6 in Block 698) and the SW4 NW4 of Block 699 and those lands in the SW4 of Block 699 lying north of the south boundary of Sections 11 and 12, T11N, R17E, U.M., Alaska and those lands in the SW4 NW4 SE4 of Block 699 and those lands in the SW4 NW4 SE4 of Block 699 and those lands in the SW4 SE4 of Block 699 lying north of the south boundary of Section 12, T11N, R17E, U.M., Alaska and east of the west boundary of Sections 7 and 18, T11N, R18E, U.M., Alaska which are within the offshore three-mile arc lines and which are all listed as state area on the "Supplemental Official O,C.S, Block Diagram" approved October 4, 1979 and December 9, 1979, respectively. Rule 1 FIELD AND POOL NAME. The field is named the Endicott Field. The hydrocarbons con- tained within the Kekiktuk Formation constitute a reservoir named the Endicott Oil Pool. Rule 2 POOL DEFINITION. The Endicott OiI Pool is defined as the accumulations of oil and gas that are common to and which correlate with the accumulations found in the Sohio Alaska Petroleum Company Sag Delta No. 4 well between the measured depths of 11,496 and 12,812 feet. Rule 3 Tn?ELL SPACING. Nominal 40 acre drilling units are established for the pool within the described area. Each drilling unit shall conform to quarter-quarter governmental sections as projected. No more than one well may be drilled into and produced from each drilling unit. The pool may not be opened in a well closer than a 1000 feet to any well opened to the pool. The pool shall not be opened in any well closer than 500 feet to the exterior boundary of the affected area. The Commission may administratively approve modifications to well spacing when justified. Conservation Or~To. 202 Page 5 September 20, 1984 Rule 4 CASING AND CEMENTING REQUIREMENTS. a) Structural casing shall be set by driving or jetting to a sufficient depth below the mud line to ensure support of drilling fluid returns to the surface while drilling hole for a conductor string. b) Conductor casing to provide for .proper anchorage shall be set at least 75 feet below the island surface and sufficient cement shall be used to fill the annulus behind the pipe to the island surface. Cement fill shall be verified by observation of cement returns. The cement may be washed out or displaced to a depth not exceeding the depth of the structural casing shoe to facilitate casing removal upon well abandonment. c) Surface casing, to provide for proper anchorage, for preventing uncontrolled flow and to protect the well from the effects of permafrost thaw-subsidence or freeze back loadings, shall be set at least 500 measured feet below the base of the permafrost but not below 2700 feet true vertical depth. Suffi- cient cement shall be used to fill the annulus behind the casing to at least the mud line. d) Surface casing types and grades approved for use include: 1) 13-3/8 inch, 72 pounds/foot, L-80 Buttress; 2) 13-3/8 inch, 72 pounds/foot, N-80 Buttress; 3) 13-3/8 inch, 68 pounds/foot, MN-80 Buttress; 4) 10-3/4 inch, 45.5 pounds/foot, K-55 Buttress; 5) 10-3/4 inch, 45.5 pounds/foot, HF-ERW Arctic Grade, J-55 Buttress; 6) 9-5/8 inch, 36 pounds/foot, K-55 Buttress; 7) 9-5/8 inch, 40 pounds/foot, K-55 Buttress; 8) 9-5/8 inch, 36 pounds/foot, HF-ERW Arctic Grade, J-55 Buttress; 9) 9-5/8 inch, 40 pounds/foot, HF-ERW Arctic Grade, J-55 Buttress; 10) 9-5/8 inch, 47 pounds/foot, L-80 Buttress. e) The Commission may administratively approve additional types and grades of surface casing upon a showing that the proposed casing and connection can withstand the permafrost thaw-subsidence and freeze back loadings which may be experi- enced. Evidence submitted to the Commission shall include: 1) full scale tension and compression testing; or 2) finite element model studies, or 3) other types of axial strain data acceptable to the Commission. f) Alternate means for maintaining the integrity of the well from the effects of permafrost thaw-subsidence and freeze back may be administratively approved by the Commission upon application and presentation of data which show the alternatives are appropriate, based upon accepted engineering principles. Conservation Or~1o. 202 Page 6 September 20, 1984 Rule 5 COMPLETION PRACTICES Wells completed for production from the Endicott Pool may utilize casing strings or liners cemented through the productive intervals and perforated, slotted liners, screen wrapped liners or open hole methods, or combination thereof. The Commission may adminis- tratively approve alternate completion methods where appropriate. Rule 6 PRESSURE SURVEYS. a) Prior to regular production, a pressure survey shall be taken on each well. b) The datum for all pressure surveys is 10,000 feet subsea. c) After regular production commences in each governmental section, a pressure survey shall be taken within six months and again within 12 months on at least one well in the section. d) Within 12 months after regular production from the pool starts, the operator will submit to the Commission for approval a key-well program setting forth the long term pressure monitoring program for the pool. e) Pressure survey, as used in this rule, means either a static bottomhole pressure survey or a transient pressure survey. f) Data from all pressure surveys shall be filed with the Commission on Form 10-412 within 45 days after the survey is taken. g) The Commission, by administrative order, may amend the key well pressure monitoring program if it is found to be inade- quate or impractical. Rule 7 GAS-OIL RATIO TESTS. a) After regular production from a well has commenced, a gas-oil ratio test will be taken within four months and each six months thereafter. b) Gas-oil ratio tests shall be a minimum of four hours duration unless otherwise administratively approved by the Commission. c) Gas-oil ratio tests will be reported on Form 10-409 and submitted within 45 days after the tests are taken. Conservation Or~1o. 202 Page 7 September 20, 1984 Rule 8 GAS VENTING OR FLARING. a) The venting or flaring of gas is prohibited except as may be authorized by the Commission for facility safety, cases of emergency or operational necessity. b) Infrequent operations where flaring is necessary, such as the initial commissioning of facilities, plant start-ups after maintenance or tie-in shutdowns and other special activities, may be administratively approved by the Commission upon written request. c) The Commission will administratively set volumes for safety flares upon receipt of a written request and accompanied by adequate data to support the request. Rule 9 GAS-OIL CONTACT MONITORING. a) A compensated neutron log shall be run in each well prior to regular production. b) A compensated neutron log shall be run in one well per governmental section within 12 months after regular production starts. c) A key-well gas-oil contact monitoring program will be submitted to the Commission for approval within 12 months after regular production from the pool commences and will constitute the long term gas-oil contact monitoring program. d) Compensated neutron logs will be submitted within 45 days after they are taken. Rule 10 GAS-OIL RATIO. a) The gas-oil ratio in a well will have no upper limit if all gas produced from the pool except quantities used in lease operations or administratively approved for other purposes by the Commission, is injected into the Endicott Oil Pool. Rule 11 PRODUCTIVITY PROFILES. a) An appropriate log to establish the productivity or infectivity profile of the intervals open to the wellbore will be run in each well within 12 months after regular production or injection commences. b) A program to monitor well productivity and infectivity will be submitted to the Commission for approval at least three months before water injection begins. Conservation Or~~To. 202 Page 8 September 20, 1984 c) Additional productivity surveys administrative order if underground waste imminent. may be required by of hydrocarbons appears d) Productivity surveys will be submitted to the Commission within 45 days after the date of the survey. Rule 12 FIELD-WIDE WATERFLOOD PROJECT. a) A field-wide waterflood project is approved for the pool area. b) The field waterflood project must be started within two years after regular production from the pool has started. c) The waterflood plan will be submitted to the Commission at least three months before actual water injection begins. d) All applications for permits necessary to implement the waterflood project shall be timely submitted for approval. Rule 13 POOL OFFTAKE RATE. a) The maximum calendar quarter average offtake rate from the pool is 125,000 barrels of oil per day. Calendar quarter average offtake rate means the daily average rate determined by dividing the total volume of oil produced in a calendar quarter by .the number of days in that calendar quarter. b) The maximum calendar quarter average offtake rate of 125,000 barrels of oil per day may be exceeded for the purpose of making up a shortfall in the allowable volume of oil produced in a previous calendar quarter providing that the offtake rate for any day does not exceed one hundred ten percent (1100 of the calendar quarter average offtake rate. c) For the purpose of providing for reasonable operating flexibility, the calendar quarter offtake volume may be exceeded. The volume of oil determined by multiplying 125,000 barrels by the number of days in that calendar quarter establishes an allowable calendar quarter offtake volume. A calendar quarter offtake volume may not exceed the allowable calendar quarter offtake volume by more than one percent (1.070 without prior approval of the Commission. Volumes of oil exceeding the allow- able calendar quarter offtake volume shall be zeroed out in the following calendar quarter by producing at rates lower than the maximum calendar quarter average offtake rate until that volume of oil produced in excess of the previous allowable calendar quarter offtake volume is offset. The volume of oil produced in calendar quarters in excess of the allowable calendar quarter average offtake rate for the purpose of recovering a shortfall in an allowable calendar quarter offtake volume as provided for by (b) above is not given consideration when making a determination Conservation Or o. 202 Page 9 September 20, 1984 for the purpose of this subsection (c). d) Gas offtake is not permitted because the reservoir depletion program governed by this order requires that produced gas be injected into the Endicott Oil Pool. At anytime, upon proper petition and after public hearing, the Commission will consider the merits of issuing an order establishing a gas offtake rate. That order would provide for appropriate amend- ments to the pool depletion program governed by this order to ensure that a loss in ultimate recovery will not occur. Rule 14 UNITIZATION. a) Oil and gas leases overlying the affected area shall be unitized and a participating area established for the Endicott Pool prior to the commencement of regular production from the pool. b) Should unitization and the establishment of a partici- pating area not be accomplished prior to regular production from the pool, this order is null and void. Upon petition and after public hearing, the Commission will issue an order setting forth pool rules governing competitive lease production methods that will ensure the protection of correlative rights and the maximum ultimate recovery from the pool or issue an order mandating pool unitization. DONE at Anchorage, Alaska A ®IL ~~~ ~~ i ~ ;' 6 ~ ~~ ~~/ ~~~ Y ~ _ ~ =~_ t b ®;~ ~ E ~ ~',,® ~~r S'M 'Y~ ~~ Y~ 20, 1984. l~~ d ~ ~-- Barry w. KUgl~', ~ommisslo r Alaska Oil and Gas Conserv tion Commission Lonnie C. Smi~ Commissioner Alaska Oil and Gas Conservation Commission Alaska Oil and Gas Conservation Commission • • a 0 a a o SARAH PALIN, GOVERNOR ALAS Oi.t.I Al`D G .~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERVATIOI~T COMI~IIS51O1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. CO 202.043 (Endicott Oil Pool, Endicott Field) ADMINISTRATIVE APPROVAL NO. CO 275.001 (Alapah and Ivishak Oil Pools, Endicott Field) ADMINISTRATIVE APPROVAL NO. CO 449.001 (Eider Oil Pool, Endicott Field) Mr. R. L. Skillern Senior Landman BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Surface Commingling of Production from Proposed Endicott Field Well 2-30B/ME-O1 with Production from Defined Endicott Field Oil Pools Dear Mr. Skillern: The Alaska Oil and Gas Conservation Commission (Commission) received your letter, dated November 20, 2008, requesting approval to commingle production on the surface from the proposed Endicott Field We112-30B/ME-O1 with production from the Eider, Ivishak, Alapah, and Endicott Oil Pools (i. e., "defined Endicott Field oil pools"). The Commission GRANTS your request subject to certain conditions as listed below. Proposed Well 2-30B/ME-O1 is on lease ADL 34633 (Tract 13), which is within the Endicott Field, but is not part of any defined Endicott Field oil pool. Based on seismic information, proposed Well 2-30B/ME- O1 production will not drain those oil pools. BP Exploration (Alaska) Inc. (BPXA) has requested that Well 2-30B/ME-O1 be allocated on a daily basis using the same methodology employed for wells in the Eider Oil Pool. Well 2-30B/ME-O1 allocated production will be based upon a minimum of two well tests per month. BPXA proposes that the allocation factor be fixed at 1.0 (i. e., it will not be adjusted for discrepancies between measurements of total Endicott Field oil production derived from well tests and from the Lease Automated Custody Transfer (LACY) meter). The Commission grants BPXA's request to commingle production on the surface from the proposed Endicott Field Well 2-30B/ME-O1 with production from the defined Endicott Field oil pools prior to custody transfer. This approval is conditioned upon the following: Unless the Commission otherwise requires, production from Well 2-30B/ME-O1 will be determined through well tests conducted at least twice per month at a stabilized flow rate lasting more than four hours. 2. Unless the Commission otherwise requires, production from Well 2-30B/ME-O1 will be allocated on a daily basis using the same methodology employed for wells in the Eider Oil Pool, with a meter allocation factor fixed at 1.0. 3. The operator shall provide the Commission with a written well test and allocation report at the end of • • Mr. L. R. Skillern January 22, 2009 Page 2 of 2 each calendar year. 4. Within one year after the start of production from Well 2-30B/ME-O1, the operator shall (1) provide the Commission a written report with all reasonably available evidence regarding whether the well is in communication with any defined Endicott Field oil pools, and (2) apply to the Commission to include the well within an already defined Endicott Field pool or within a new Endicott Field pool. 5. Unless notice and a public hearing are required, upon proper application or its own motion, the Commission may administratively amend this order as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. ENTERED at Anchorage, Alaska, and dated January 009. ~. ,._~~. -~ • ~ t)i r~°' ~ * ~,_ Daniel T. Seamount, Jr., Chair Cathy P. oerster, Commissioner :, ;~: , :~ 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsid- eration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for re- consideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Fail- ure to act on it within 10-days is a denial of reconsideration. If the Commission 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 Commission mails, OR 30 days if the Commission 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 af- ter the date on which the application for reconsideration was filed. If the Commission 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 Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission oth- erwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on ap- peal are limited to the questions presented to the Commission 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 unti15:00 p.m. on the next day that does not fall on a weekend or state holiday. ~~ a ~ a a a 0 FRANK H. MURKOWSKI, GOVERNOR oaI[~~7~ OIIr ~ ~ 333 W. 7TM AVENUE, SUITE 100 CO1~T5ERQATI011T CODiDIISSI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 202.42 Ms. Katie Nitzberg Endicott Staff Geologist BP Exploration (Alaska) Inc. P. 0. Box 196612 Anchorage, AK 99519-6612 Re: Spacing Exception for Endicott 2-28B/ 0-19 Well Ms. Nitzberg: The Alaska Oil and Gas Conservation Commission ("Commission") has received your correspondence, dated March 10, 2003, requesting a spacing exception for drilling and completion of the Endicott 2-28B/0-192-28B/0-19 well. Well 2-28B/0-19 will be a producer in Subzones 2A and 2B of the Kekiktuk Formation. Nearby existing well 1-05/0-20 is a gas injector that is also completed in Subzone 2B of the Kekiktuk Formation. Rule 3 of Conservation Order 202, which governs this area, states: "The pool may not be opened in a well closer than 1000 feet to any well opened to the pool." The information you submitted indicates the interval intended for completion within 2-28B/0-19 is approximately 960 feet horizontal distance and 490 ft. vertically from the 1- 05/0-20 existing well. The separation between this proposed producer and the existing injector are substantively equivalent to the requirements of Rule 3 in Conservation Order No. 202. The Commission has determined drilling and completion of the Endicott 2- 28B / 0-19 well will not promote waste, will enhance recovery, and hereby approves the drilling and completion of the well within Kekiktuk Subzones 2A and 2B as proposed pursuant to Rule 3 of Conservation Order No. 202. DONE in Anchor e, Alaska this 12~ day of March 2003. ~~ _ . f ~ ~~. ,1 ~i Sarah Palin `` Randy Ruedrich ~; Commissioner Commissioner ,s~'1.,Y BY ORDER OF THE COMMISSION fi° ~ ~ d f; ,\;Vi~~f ~, ;Y ~ ~; ~ ~ _ .~ .~ ~ n __ r~~ a, ~., ~ ~'~ ` `~'~ ~ ~ ~.~. o ~ a o d FRANK H. MURKOWSKI, GOVERNOR 1~~TT~+ ~r -rnrS~a~T ~~ ~`17~7 333 W. 7TM AVENUE, SUITE 100 C~1`SLi RQAii~ts CD~~IIS''~7''I0~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ADMINISTRATIVE APPROVAL N0.202.41 FAX (907) 27sa542 Ms. Katie Nitzberg Endicott Staff Geologist BP Exploration (Alaska)1nc. P. 0. Box 196612 Anchorage, AK 99519-6612 Re: Spacing Exception for Endicott 3-17E/K-30 Well Ms. Nitzberg: The Alaska Oil and Gas Conservation Commission ("Commission") has received your correspondence, dated February 19, 2003, requesting a spacing exception for drilling and completion of the Endicott 3-17E/K-30 well. Well 3-17E/K-30 will be a producer in Subzone 2A of the Kekiktuk Formation. Nearby existing well 3-07A/L-29 is a producer that is completed in this same interval. Rule 3 of Conservation Order 202, which governs this area, states: "The pool may not be opened in a well closer than 1000 feet to any well opened to the pool." The Commission understands that the interval intended for completion within 3-17E/K-30 is approximately 975 feet horizontal distance from the existing 3- 07A/L-29 well. These two wells lie on opposite sides of the Midfield Fault, which is a sealing fault based on reservoir pressure information. Because these wells lie on opposite sides of a sealing fault, production from Kekiktuk Subzone 2A in we113-17E/K-30 will not interfere with production from well 3-07A/L-29. The Commission has determined drilling and completion of the Endicott 3-17E/K-30 well will not promote waste, will enhance recovery, and hereby approves the drilling and completion of the well within Kekiktuk Subzone 2A as proposed pursuant to Rule 3 of Conservation Order No. 202. DONE in Anchorage, Alaska this 21 S` day of February 2003. p Daniel T. Seamount, Jr. Commissioner / ~ alin Commissioner d~~~ ~ ! v ~;x ~ ~ ~ BY ORDER OF THE COMMISSION ~ ~ ~ : ~~~ ~ ~ ~ `8~ .~ ~r~. .~ ~ _ '; -i ,, ~'~. io ~ s ,( A.: _ i~ y ,'~ a o o a 0 FRANK H. MURKOWSKI, GOVERNOR ~T~+~t 4i1[L17S~aAT 0~ ~ VrOt-7T 333 W. 7TM AVENUE, SUITE 100 C~l~-7~RQA~~1s C~~`IIsSI01` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 ADMINISTRATIVE APPROVAL N0.202.40 Ms. Katie Nitzberg Endicott Staff Geologist BP Exploration (Alaska) Inc. P. 0. Box 196612 Anchorage, AK 99519-6612 Re: Variance Exception for Endicott 4-10/L-28 Well Ms. Nitzberg: The Alaska Oil and Gas Conservation Commission ("Commission") has received your correspondence, dated February 19, 2003, requesting a variance exception for perforating a productive interval within the Endicott 4-10/L-28 well. The proposed 4-10/L-28 well will be a producer in Subzone 2A of the Kekiktuk Formation. Nearby existing we113-07A/L-29 is a producer that is completed in this same interval. Rule 3 of Conservation Order 202, which governs this area, states: "The pool may not be opened in a well closer than 1000 feet to any well opened to the pool." The Commission understands that the interval intended for perforation within 4-102-28 is approximately 700 feet horizontal distance from the producing interval in well 3-07A/L-29. These two wells lie on opposite sides of the Midfield Fault, which is a sealing fault based on reservoir pressure information. Because these wells lie on opposite sides of a sealing fault, production from Kekiktuk Subzone 2A in we114-10/L-28 will not interfere with production from we113- 07A/L-29. The Commission has determined perforation of the Endicott 4-10/L-28 well will not promote waste, will enhance recovery, and hereby approves the perforation of the well within Kekiktuk Subzone 2A pursuant to Rule 3 of Conservation Order No. 202. DONE in Anchorage, Alaska this 19th day of February 2003. _~/ ~~. Daniel T. Seamount, Jr. Commissioner .~~~ .,.. ~~ ~~ 1 C... _., _ Sarahm m Randy Ruedrich Commissioner G~ Commissione.~,~.~„~ BY ORDER OF THE COMMISSION \ ~~' ~ ;,: ~ ~~ 9 A , ~ 1 u ~ , * la, __ 5 ... I'~ '' ' A l 1 = ~ ~~° a,° 9 N~Y G,~ ~ ~ .. mow{ ~~, _~ ~ TONY KNOWLE^~ GOVERNOR a_~ ~~ ~BA OIL AN~D+ GA-5 333 W. 7m AVENUE. SUITE 100 CONSERQA~'ION COririISSION ANCHORAGE, ALASKA 59501-3539 PHONE. (907) 279-1433 FAX (907) 2767542 ADMINISTRATIVE APPROVAL N0.202.~ ~~ Re: Spacing. Variance for Endicott 2-28/0-19 Well Mr. Jeff Hupp Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage,. AK 99519-6612 Dear Mr. Hupp: We have received your correspondence dated January 25, 2001 requesting a spacing variance for the Endicott 2-28/0-19 well. As proposed, the bottom hole location of 2- 2810-19 is approximately 200 feet horizontal distance from the. existing 2-14/0-16 well. The proposed 2-28/0-19 well will be drilled as a high-angle producer in .Subzone 2B of the Kekiktuk Formation. Existing well 2-14/0-16 is a production well completed in Kekiktuk Subzone 2A. Subzone 2B is separated from the underlying Subzone 2A by the K2M shale, which is a barrier to vertical flow. Recent static pressure .measurements in this area indicate a pressure differential of approximately .280 PSIA° exists between Subzones 2A and 2B. Drilling and completion of the 2-28/0-19 production well will not interfere with production from the adjacent 2-14/0-16 well. ,The Commission has determined placement of the well will not promote waste, .will enhance recovery, and hereby approves the drilling of the Endicott 2-28/0-19 well as proposed pursuant to Rule 3 of Conservation Order No. 202. ~i Daniel T. Seamount Jr. C~~nm 'Ta for Julie Heusser Y Y Commissioner Commissioner Commissioner DONE in Anchorage, Alaska this ~~ day of February, 2001. BY ORDER OF THE COMMISSION ~ • ALASSA OIL A1~TD GAS COI~TSERQATIOI~T COMl~IISSI01~ -ONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: ;907) 276-7542 August 10, 1998 ADMINISTRATIVE APPROVAL VO. 202.38 Re: An amendment to Conservation Order 202 Rule l3(d) to allow gas export from the Endicott Oil Pooi. North Slope. Alaska. Simon Potter BPXA Production Manager, Eastern North Slope BP Exploration (Alaska). Inc. P. O. Box 196612 Anchorage, Alaska 995 1 9-66 1 2 Dear Mr. Potter: We have received your letter of June 26. 1998 seeking an amendment to Conservation Order 202 Rule 13(d) to allow export of gas from the Endicott Oil Pool. The exported gas will be used as fuel and source gas for an enhanced oil recovery project at the Badami Oil Pool. The Commission published notice of opportunity for public in the Anchorage Daily News on July 11, 1998.. No protests were filed with the Commission. On July 30, 1998- the Commission requested additional information. BPX personnel met with AOGCC staff on August 6, 1998 to provide additional information supporting the petition. Conservation Order 202 was adopted September 20, 1984, to govern initial development and depletion of the Endicott Oil Pool. Initial projections estimated the pool would produce up to 375 million barrels oil (OOIP was estimated at 1. l billion barrels} under primar<• depletion in combination with apool-wide waterflood. Gas sales were anticipated within scvento eight years from start up, however- the opportunity for gas sales has not materialized until recently. Cumulative liquids production has exceeded initial projections by optimizing waterflood. dcbottlenecking facilities and exploiting recovery of reserves b~ cycling gas and vaporizing residual oil in swept zones. The operator and owners estimate ultimate recovery of 620 million barrels from the Endicott Oil Pool at this time. The volume of gas exported to Badami will be up to 2> million SCF per day, for a total of approximately 100 BCF over the life of the project. The operator estimates the impact on recovery in the Endicott Oil Pool will be minimal, about 700,000 barrels of vaporized h~•drocarbons or 0.1% of ultimate recoverable liquids. The reduced recovcrv is well ~t ithin the accuracy of predictive methodology for evaluating vaporization recovcrv. The impact on reservoir voidage can be mitigated by increasing water injection 1500 to 2000 barrels per day on an average annual basis over the life of the project. The Commission concludes that the impact on ultimate recover and reservoir voidage in the Endicott Oil Pool is minimal. The estimated reduction in vaporization recovery is statistically . • • insignificant. and will be more than offset by additional oil recovery from the Badami Oil Pool, as well as by the commercialized value of the exported gas. Accordingly. the export of gas from the Endicott Oil Pool at rates up to 2~ ~1MCF per day is not likely to cause waste. jeopardize correlative rights or harm ultimate recovery. Therefore, pursuant to Rule 13(d) CO 202, the Commission establishes a gas offtake rate up to 25 million SCF per day from the Endicott Oil Pool, not to exceed 100 BCF over the life of the project. Export volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 1,0-422 as part of the gas disposition report. The gas offtake rate is subject to review should adverse performance cause conditions to change or other unforeseen circumstances develop that would materially change the basis for this decision. Sincerely. David W. Johnston obert N. ristenson, P.E. Camille Oechsli Chairman Commissioner Commissioner BY ORDER OF THE COMMISSION C'. S1SnFF1CE~WINWORD FIELDS\ENDICOTTa:AZ0;-3R DOC D~VJ ~, ~ ~ ~ ~ t ~ ~-^~ ~--~ ~~ ~ TONY KNOWLES, GOVERNOR ~. ~, 7~T ~1 A~S~g UITi ~ ~-7 3001 PORCUPINE ORIVE C~1~-71IRQ1~'.CIO1Q CU1~Il~IISSIUlY ~ ANGHORAGE, ALASKA 99501-3192 1 PHONE: {907) 279-1433 FAX; (907) 278-7542 December 28, 1995 ADMINISTRATIVE APPROVAL N0.202.37 Re: Spacing exception for Endicott 1-5910-24 well Mr. Robert R Metzger ..Area. Production Engineer BP Exploration {Alaska) Ina P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Metzger: We have received your correspondence dated December 18, 1995 requesting a spacing variance for the Endicott 1-59/0-24 well: As proposed, this well will penetrate the top of the 2B interval of the Kekiktuk Formation within 175 feet of the 5-02/SD-10 well. Well 5-02/SD-10 is a water injection well completed in the Zone 2A interval of the Kekiktuk Formation. The subject well will be drilled as a horizontal producer in the 2B interval. The .drilling and completion of the 1-59/0-24 2B zone production well will not interfere with 2A zone injection operations in the adjacent 5-02/SD-10 well. The Commission has determined placement of the well will not promote waste, will enhance recovery, and hereby approves the drilling of the Endicott 1-59/0-24 well as proposed pursuant to Rule 3 of Conservation Order No. 202. Sincerely, „ ~ C""7 .. r°- ~ ~ ~ ~ a o a ~~ ~,,! f t, ~f ~ ;. WALTER J. NICKEL, GOVERNOR ALASKA O1L AND GAS 3001 rvxcvPUVtr nxly$ CONSERVATION COMMISSION ANCHO1tACE,ALASxA 99501-3192. PHONE: , (90'T)E'79-1433 TELECOPY: (907)27&7542 November 29, 1994 ADMINISTRATNE APPROVAL N0.202.36 Re: .Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter oC November 28, 1994 requesting additional flare volume for the Endicott oil pool production facility in the Duck Island Unit (DIU). The additional flare volume is required during testing of the recently repaired gas compressors. The Commission hereby approves flaring up to 330 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring. is expected [o commence an or about November 29, 1994 and. continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes wilt be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. DONE at Anchorage, Ataska and dated November 29, 1994. FI N David W. Joh ton, Commi loner Ataska Oil an~Gas Conscrva 'on Commission G~*' . Russell A. Douglass, Commissi er Alaska Oil and Gas Conservation Commission ~~4 r~.~~i~~- ~~ uckernlan Babcock, Commissioner Alaska Oil and Gas Conservation Commission ~x> ~x~ ~xiirted ern recycled pap°~r ~~ ~~ G. ~~ 6 ~: Q 0 Q WALtER J. NICKEL, GOVERNOR ALA5IfiA OIL A1~D GA5 3001 PORCUPINE DRIVE . CON5EIiVATIOI~T COI•IMI55I011T ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TEtECOP1(: (907) 278.7642 June 22, 1994 ADMINISTRATIVE APPROVAL N0.202.35 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612. Dear Ms. Cooke: We have received your letter of June 17, 1994 requesting additional flare volume for the Endicott oil pool production facility in the Duck Island Unit (DIU). The additional flare volume is required during repair of a main gas compressor recycle valve. The Commission hereby approves flaring up to 20 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about June 23, 1994 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil. and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, ~. Russell A. Douglass Commissioner BY ORDER OF TI3E COMMISSION ~~~,~Pa ~~, ~~ sled ~ ~ v ~,,,~~I•~c;~~ ~ a a d i O WALTER J. NICKEL GOVERNOR ALASIfA OIL AND GAS. 3001 PORCUPINE DRIVE '* ~ CONSERVATION COMMISSION ANCHORAGE, ALASKA89501-3182 PHONE: (907} 2T9-1433 TELECOPY: (907) 2T8-T542 June 6, 1994 ADMINISTRATIVE APPROVAL N0.202.34 Re: Additional .flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke ~ , BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612. Dear Ms. Cooker We have received your letter of June 3, 1994 requesting additional flare volume for the Endicott oil pool production facility in the Duck Island Unit (DIU). The additional flare volume is required during operational testing of the main gas compressors. The Commission hereby approves flaring up to 180 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about June 9, 1994 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, Q ,~~ Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION primed on recycled p~pef b y G. t;~. • ~`~~~ ~~~ ~~ ~ 1T ~ ~ {; ~.-, (i'11 ~~ X11 ALASKA OIL A1~TD GAS COI~TSERYATIOI~T COMMISSIOlY March 25, 1994 a ~ WALTER J. H/CKEL, GOVERNOR d ,' 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 ~ PHONE: (907)279-1433 ? TELECOPY: (907) 27&7542 ADMINISTRATIVE APPROVAL NO. 202.33 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit Alison D. Cooke BP Exploration (Alaska) Inc. P. O: Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of March 25, 1994 requesting additional flare volume for the Endicott oil pool production facility in the Duck Island Unit {DIU). The additional flare volume is required during repair operations on the A and B main gas compressors: The Commission hereby approves flaring up to 400 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about March 26, 1994 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All .gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION - ~~ printed on recydee paper b y C. D. • a Q a -• WATER J. H1CKEt, GOVERNOR ALASIfA OIL Al~TD GAS 3001 PORCUPINE t?RIVE CO1~T5ERVATIOIIT COMMI5SI011T nNCHORn~E,ALASKA9950131s2 PHONE: (90~ 279-1433 TELECOPY: (907) 276-7542 February 23, 1994 ADMINISTRATIVE APPROVAL N0.202.32 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear. Ms. Cooke: We have received your letter of February 23, 1994 requesting additional flare volume for the Endicott oil pool production facility in the Duck Island Unit (DIU). The added flare volume is required because additional work will be done on the B-main gas compressor air control system which was not anticipated at the time of the previous flare request dated February 21, 1994.. . The Commission hereby approves flaring up to 100 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on ox about February 24, 1994 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be'reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, ....~.....u.. BY ORDER OF THE COMMISSION ~ir~tr.,irrn rrfyclt'~1P~{apt ii i~ t-_4} ~~'Q~~ 0~ a~Q~aQ ALASSiA OIL AND GAS CONSERVATION COMMISSION February 22, 1994 WAITER J. HtCKEt, GDVERNOA 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 995013182 PHONE: (807)279-1433 TELECOPY: (907J 27&7542 ADMINISTRATIVE APPROVAL N0.202.31 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of February 21, 1994 requesting additional flare volume for the Endicott oil pool production facility. in the Duck Island Unit (DIin. The additional flare volume is required during inspection and repair of the third stage anti-surge valves on the A and B-main gas compressors. The Commission hereby approves flaring up to 100 MMcf of gas aver and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about February 22, i 994 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease. operation. Q i r~nnrnly BY ORDER OF THE COMMISSION printed on recycled pape+ b y C. i? . .. b, a ~~ ~' ALASS-A OIL AIYD GAS COI~TSEIiVATIOI~T COMMISSIOI~T February 7, 1994 .WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAf3E, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPI": (907)27&7542 ADMINISTRATIVE APPROVAL N0.202.30 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of February 3, 1994 requesting additional flare volume for the Endicott oil pool production facility in the Duck Island Unit (DIU). The. additional flare volume is required during repair of a valve on the B-main gas compressor. The Commission hereby approves flaring up to 100 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about February 6, 1994 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION J nr ~..e+tl ore rKrey~ '+~~ ; f: +R ,., i3 ; b ~ ~ ~ ~ WALTER J. HICKEY GOVERNOR ALASFiA OIL A1~TD GAS soon P©RCUPINE oRiuE COI~TSEItYATION COMMISSIO1tiT aNCHOF+aaE, au-srca 9s5o1-3192. PHONE: (9p~ 279-1433 October 19, 1993 TELECONY: (907) 276-7542 ADMINISTRATIVE APPROVAL N0.202.29 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6b12 Dear Ms. Cooke: We have received your letter of October 19, 1993 requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU). The additional flare volume is required during scheduled maintenance on the B-main gas compressor. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 100 MNIcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about October 19, 1993 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, ~.a~~if'iC' ~ a.~~ Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION printed on recycled paper b y G: f_l. WALTER J. HlCKEL, GOVERNOR ALASIfA OIL A1~D GAS 3001 PORCUPINE DRIVE CO1fTSERVATIOiK COMMISSIOl~ nNCNORac~E, nu-sKn 9sso1-3192 PHONE: (907) 27'9-1433 TELEC©PY: (~ 276-7542 September 17, 1993 ADMINISTRATIVE APPROVAL NO.202.?.llr Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of September 17, 1993 requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU). The additional flare volume is required during repairs of a leaking flange on the wellhead of the 1-15 gas injection well The Commission finds the additional flare volume to be an aperationa} necessity, and hereby approves flaring up to 15 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about September 18, 1993 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever passible, and all ' volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, ~...~~ ~ Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION =j K,rir,tpd nr~ reeyc~cd pa{~Pr ~ v C;.t?. O ~ ~ ~ WALTER J. HICKEL, GOVERNOR ALASKA OIL A1~TD GAS 3004 PORCUPINE OR1VE C01~5ERQATIOI~T COMMISSIOI~T ANCHORAQE, ALASKA 995013192 PHONE: (907j 279-1433 July 8, 1993 TELECOPY: (907) 276-7542 AD 0.2 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit.. David Lowe, Acting Supervisor Environmental Compliance, Alaska BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Mr. Lowe: We have received your letter of July 8, 1993 requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU). The additional flare volume is required during repair of a main compressor valve, which failed on the night of July 7, 1993. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 500 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about July 8, 1993 and continue until work is complete. , It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, ~. Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION printed on recycled paper h y tw! t7. ~, ~.....1 r._~~ ..__.~ -~ ~ ~ .~ s , / ^ ~ ~ ~ ( ~ t ' ~ ~k WALTER J. NICKEL, GQVERNOR f' ~ ~~ ! ~ + ALASI~iA OIL A1~TD GAS 300t PORCUPINE DRIVE COi1TSEIi~ATIO1~ COMMISSIOI~T ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 278-7542 June 28, 1993 ~. Re; Additional flare volume Endicott Oil Pool production facilities, Duck Island Unit. Alison D Cooke BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Dear Ms Cooke: We have received your letter of June 24, 1993 requesting~additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit. The additional flare volume is required during completion operations for the 1-15 gas injection well. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 80 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about June 28, 1993, and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and ail volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Yours very truly, -'C-+' ~• Russell A Douglass Commissioner BY ORDER OF THE COMMISSION (~ ` ~ " ~ ~ ~ ~ r ~ ~~ ~ (~ ~ ~ ~ ~ (~ (r~1~ hs ~ ~ ~~ WAtTER J. NICKEL, GOVERNOR t .~~ s, 3I ~ ~ ~ ~~~1 I ~ ~ ~~. ~r~1~ k. ~ .~._~ ~~'~ .I ~I 1~ ._:~~(1b~ ~ sx ~~. ~° ALASKA OIL A1~I) GA5 3001 PORCUPINE DRIVE CONSFiR-`lATIO1~T COMMI5SION ANCHORAGE, ALASKA 99501-3192 PHONE: (907)279.1433 TELECOPY: (907)27&7542 June 21, 1993 ADMINISTRATIVE APPROVAL N .202.25 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of June 17, 1993 requesting additional flare volume far the Endicott Oil Pool production facilities in the Duck Island Unit (DIU}. The additional flare volume is required during the shutdown of the second Main Compressor Train during the scheduled upgrade of the system explained in your May 4, 1993 correspondence. The Commission understands the upgrade operations for the first train took longer than estimated (21 Vs 18 days) and the same amount of time is now projected for the remaining upgrade. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 360NIlVicf of gas over and above the designated safety flare of the Endicott production facility. This is in addition to the volume approved in Administrative Approval 202.24. Flaring is expected to commence on or about June 21, 1993 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. .Sincerely, ~~~ Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION • • 'WALTER J. NICKEL, GOVERNOR ALASI~iA OIL AI~TD GAS 3001 PORCUPINE DRNE COI~SER~ATIOI~T COMMISSIOI~T ANCHORAt3E, ALASKA 99501-3192 PHONE: (90~ 279-1433 May 10, 1993 rELECOPV: (sm~ 2~s-7542 ADMINISTRATIVE APPROVAL N0.2U2.24 Re: Additional flare volume, Oil Pool production facilities, Duck Island Unit. Mr. Steven D. Taylor, Mgr. Environmental & Regulatory Affairs, Alaska BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Mr. Taylor: We have received your letter ofMay 4, 1993 requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU). The additional flare volume is required during the shutdown of each Main Compressor Train during scheduled upgrades for the systems. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 4320MMcf of gas. over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about May 24, 1993 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION e ~ a s o ALASKA OIL A1~D GAS COI~SERVATI01~ COMMISSIOI~T March 31, 1993 ADMINISTRATIVE APPROVAL N0.202.23 WALTER J. HICKEt, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA99501-3192 PHONE: (907j 279-1433 TELECOPY: (807) 276-7542 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of March 24, 1993 requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU). The additional flare volume is required during the shutdown of each Main Gas Compressor for cleaning operations. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 300MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected;to commence on or about April 18, 1993 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, Russell A. Douglass Commissioner BY ORDER OF TIIE COMMISSION printed on recycled paper b y v:(7. 0 ~ ~ WALTER J. HICKEL, GOVERNOR ALASIfA OIL AIiTD GAS 3001 PORCUPINE DRiVf COI~SER{~ATIOl~ COMMISSIOl~ ANCHORACif, ALASKA 99sot-3192 PHONE: (907) 279-1433 March 22, 1993 TELECOPY: (907) 276-7542 ADMINISTRATIVE APPROVAL 0...202.2 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of March 22, 1993 requesting additional flare volume for the Endicott Oil Pool production facilities in the I~„Island Unit (DIU). The additional flare volume is required during operations to tie-in well 2~ to the gas injection system. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 175 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about March 22, 1993 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, nn ~, .b~ Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION printed on recycled paper b y C: Ct. O ~ WALTER J. NICKEL GOVERNOR ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501.3192 PHONE: (907) 279-1433 TELECOPY: (907) 27&7542 March 4, 1993 ADMINISTRATIVE APPROVAL NO. 202.21 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island .Unit. Alison D . Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of .March 4, 1993 requesting .additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU) . The additional flare volume is required while .repairing B-booster compressor motor. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 48 MMef of gas over and above the designated safety flare of the Endicott production facility.. Flaring. is expected to commence on or about March 4, 1993 and continue until work is complete . It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and wily be disposed of in a safe manner by flaring or used for lease operation. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION Aria o ~ a o 0 WALTER J. NICKEL, GOVERNOR AL~SI~-1~ UII,1~1~iD (ir,~,S 3001 PORCUPINE OHIVE CUI~SERV~f-TIUN CUDIPIISSIUl~ ANGHORAaE, ALASKA 99501-3192 ' PHONE: (907) 279-1433 March 3, 1993 TELECOPY: (907)276-7542 ADMINISTRATIVE APPROVAL NO. 202.20 Ite: Additional flare volume, Endicott Uil Pool production facilities, Duck Island Unit. Alison D . Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms . Cooke We have received your letter of February 24, 1993 requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU) . The additional flare volume is required while perforating well 2-12/Q-16. The well will be backflowed to reduce hydrostatic pressure, reduce formation damage and help clean up the perforations . The Commission finds the additional flare volume to be an operational necessity, .and hereby approves flaring up to 165 MMef of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about March 30, 1993 and continue until work is complete . It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All -gas produced in excess of the 1200 Mef/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, ~~. Russell A. Douglass, Commissioner BY ORDER OF THE COMMISSION printed nn recycled paper b y C.n, t WALTER J. NICKEL, GOVERNOR ALASKA OIL A1~TD GAS 3001 PORCUPINE DRIVE COI~TSERQATION COMMISSION ANC1ioRAGE, ALASKA 995013192 PHONE: (907)279-1433 TELECOPY: (907) 276-7542 February 5, 1993 ADMINISTRATIVE APPROVAL N 202.1~~ 9 Re: Additional flare volume, Endicott Oil Pool. production facilities, Duck Island Unit. Mr. Steven D. Taylor, Mgr. Environmental & Regulatory Affairs, Alaska BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Mr. Taylor: We have received your letter of February 4, 1993 requesting additional flare volume for the Endicott 0iI Pool production facilities in the Duck Island Unit {DIU). The additional flare volume is required while drilling well 2-12/Q-16. While drilling the surface hole, operations will occur in close proximity to the 2-06/J-22, one of three gas injection wells. During this time BPX will shut down 2-06/J-22 in the interests of safety, and resume injection when drilling. operations are no longer in close proximity. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 180 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about February 8, 1993 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf/d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, Russell A. Douglass Commissioner BY ORDER OF T8$ COMMISSION ~~ printed on cecyciGd ^,zca~ ~ ', ,. • WALTER J. HICKEL, GOVERNOR ALASKA OIL ANII GAS 3001 PORCUPINE DRIVE COI~TSER~ATIOlY COMMISSIOI~T ANCHORAGE, ALASKA 99501-3192 PHONE: {907) 279-1433 TELECOPY: (907) 276-7542 January 12, 1993 ADMINISTRATIVE APPROVAL NO. 202.18 Re: Additional flare volume, Endicott Oil .Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of January 12, 1993 requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU) . The additional flare volume is required to facilitate repairs of four fin fans in the second and third stage coolers in module 302 of the DIU facilities . The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 160 MMcf of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about January 12, 1993 and continue until work is complete . . It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas. Conservation Commission form 10-422. All gas produced in excess of the 1200 Mcf / d safety flare volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation. Sincerely, ~~ Russell A . Douglass Commissioner BY ORDER OF THE COMMISSION ~ ,v C f '~ f ! ~ I fr~ ~ 1 ,., S ~ ~ ~ ' ~ ~ ! ~ `~ ~ ` ' ~ 1 ~ ~~ a ; ~' WALTER J. NICKEL, GOVERNOR .. ~ ,.1 ,,1 i~ ,---~ ~C 1 ~.:_, _~ ~ r ALASI~-A OIL AlYD GA5 3001 PORCUPINE DAIVE CO1~T5ERVATI011T COMMISSIOI~T f ANCHORAGE, ALASKA 99501-3192 PHONE: (907)279-1433 TELECOPY: (907) 27E7542 November 13, 1992 ADMINISTRATIVE APPROVAL NO.202.17 Re: Spacing Exception Duck Island Unit (D.LU) we113-03/J-33. Mr. Paul Chan Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage,. AK 99519-6612 Dear Mr. Chan: We have received your letter of November 5, 1992 requesting an exception to .Conservation Order (C.O.) No. 202, rule 3 in order to drill and produce D.LU. we113-03/J-33. The proposed bottom hole location for this well is 465' SNL, 2567 WEL, Section 4, Tl1N, R17E., UM, The distance between proposed we113- 03/J-33 and existing we113-15/K-33 is approximately 441 feet at total depth. After reviewing your correspondence dated November 5, 1992 and Katie Nitzberg's dated November 12, 1992, the Commission finds that the drilling of D.I.U. we113-03/J-33 to a proposed bottomhole location 465' SNL, 2567' WEL in Section 4, T11N, R17E, UM will exploit significant reserves which are not recoverable from existing wells. Persuant to Endicott Pool Rule 3 in C.O. No. 202, the Commission grants BP Exploration administrative approval to drill D.LU. we113-03IJ-33 to the above referenced proposed bottomhole location. BY ORDER OF THE COMMISSION xit;tE~tl iJn Ir~•y Lln~ ~. y~~tiw ~. V ~~; ~;~ ' ~a !~ ' ' j ? ~ 1;~,`~ ~ WALTER J. NICKEL, GOVERNOR [ ~ f ~ ~ ~ I ,ja 1~~ i ~~ ALASFIA OIL A1~TD GAS 3001 PORCUPINE DRIVE COI~SER~ATIOlY COMMISSIOl~ ANCHORAGE, ALASKA 99501-3192 PHONE: (90'n 2T9-1433 July 15, 1992 TELECOPY: (90276-7542 ADMINISTRATIVE APPROVAL NO. 202.16 Re: Additional flare volume, Endicott Oil Pool production facilities, Duck Island Unit. Mr. Steven D. Taylor, Mgr. Environmental & Regulatory Affairs, Alaska BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Mr . Taylor We have received your letter of July 10, 1992, requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit (DIU) . The additional flare volume is required during shutdown and startup of the DIU facilities associated with causeway breach work. The Commission finds the additional flare volume to be an operational necessity, and hereby approves flaring up to 92 MMef of gas over and above the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about July 24, 1992 and continue until work is complete . It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 1200 Mef/d safety flare volume is subject to AS 43.55..020, and will be disposed of in a safe manner by flaring or used for lease operation . Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION +~ f I ,! ), l+41 ~ fi , I1 ~. ~ WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276 7542 June 29,1992 ADMINISTRATIVE APPROVAL NO. 202.15 Re: Increase safety flare for the Endicott Field, Endicott Oil Pool production facilities . Tim Tyler Manager, Endicott Development BP Exploration (Alaska). Inc. P. O. Box 196612 Anchorage, AK. 99519-6612 Dear Mr. Tyler: We have received your correspondence dated May 18, 1992 requesting an increased safety .flare volume for the Endicott Field, Endicott Oil Pool production facilities . Data submitted to the Commission at an April 27, 1992 meeting with BPX representatives and your summary correspondence support increasing the Endicott. safety flare volume to accommodate operational changes . Although the increase is supported, the Commission has undertaken a review of safety -flare practices at oil and gas production facilities in the- state. Pending the outcome of this review the commission hereby approves the flaring of gas to maintain safety flares and to permit purging of gas handling equipment at the rate of 1200 MCF per day for the Endicott Field, Endicott Oil Pool production facility. The daily average rate shall be calculated on a monthly basis . This approval supersedes administrative Approval No. 202.4 and will remain in effect until December 31, 1992. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION ~,~~r...~„-i..~r.~~,,,; ~ ~.~ . ; , ~ f ~ v ~, WALTERJ. HICKEL, GOVERNOR t1L~SK~ OIL A~TD Gr1S 300, PORCUPINE DRIVE CO~TSERQATIOIT CO~I:~IISSIOIQ ANCHOance, Af1~SKA ssso,~s2 PHONE: (907) 279-1433 TELECOPY: (907)276-7542 February 24, 1992 ADMINISTRATIVE APPROVAL NO. 202.14 Re: Additional flare volume, Endicott .Oil Pool production facilities, Duck Island Unit. Mr. Steven D. Taylor, Mgr. Environmental & Regulatory Affairs, Alaska BP Exploration (Alaska} Ine. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Mr. Taylor: We have received your letter of February 18, 1992, requesting additional flare volume for the Endicott Oil Pool production facilities in the Duck Island Unit. ~ The additional flare volume is required .during performance testing of the flare. The Commission finds the additional flare volume to be an operational ~ necessity, and hereby approves flaring up to 50 MMef of gas .over and above the designated safety flare pilot of the Endicott production facility. Testing is expected to commence on or about February 25, • 1992, and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the 400 Mcf/d safety flare pilot volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation . Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION ~,~ ~ ~ ~ Q ALASN-A OIL A1~D GAS COl~TSERVATIOI~T COMMISSIOI~T October 11, 1991 WALTER J. NICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE; ALASKA 99501.3182 PHONE: (907)27'9-1433 TELECOPY: (~ 276-7542 ADMINISTRATIVE APPROVAL NO. 202.13 Re: Additional flare volume, Endicott Oil Pool production facilities,. Duck Island Unit. Mr. Steven D. Taylor Environmental Compliance & Regulatory Affairs BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Mr. Taylors We have received your letter of October 11, 1991, requesting .additional flare volume for the Endicott Oil Pool production facilities in the Duek Island Unit. The additional flare volume is required during repair of the leaking third stage discharge manual block valve on the gas injection header. The Commission finds the additional flare volume to be an operational- necessity, and hereby approves flaring up to 80 MMcf of gas over and above the designated safety flare pilot of the Endicott production facility. Repairs are expected to commence. on or about October~-12, 1991, and continue .until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation .Commission form 10-422. All gas produced in excess of the 400 Mcf/d safety flare pilot volume is subject to AS 43.55.020, and will be disposed of in a safe manner by flaring or used for lease operation . Sincerely, Russell A. Douglass Commissioner BY ORDER OF TAE COMMISSION printed on recycled paper b y C.Ly. O WALTER J. NICKEL, GOVERNOR 4 o e a o ALASKA OIL A1~D GA5 3001 PORCUPINE DRIVE COI~TSF,RVATIOl~T COMMI55IO1~T ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907} 276-7542 October 14, 1991 ADMINISTRATIVE APPROVAL N0.202.12 Re: Spacing exception for Endiec~tt 2-54JQ-12 MPI well Mr. Paul Chan Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Chan: We have received your correspondence dated October 7, 1991 requesting a spacing exception for the Endicott 2-54/Q-12 MPI well. As proposed, the well will penetrate the top of the Kekiktuk Formation within 577 feet. of the 2-44/R-12 well and 846 feet of the 2-42/P-13 well. Well 2-54/Q- 12 is programmed as a water injection well to be completed in the Zone 3A interval. Neither of the immediately adjacent wells are to be completed in Zone 3A. The Commission has determined placement of the well will not promote waste, will enhance recovery, and hereby approves the drilling of the Endicott 2-54/Q-12 MPI well as proposed pursuant to Rule 3 of Conservation Order No. 202. Sincerely, Russell A. Douglas Commissioner BY ORDER OF THE COMMISSION ~elac~pT ~o. {907) 216-~~42 Deee~aber 31. 1990 ADMZI~ZBTRA?ZVE A~~ YAI. 20~ 21 R+~a 8f-~6ing aseeptic+ra far Endicatt 9-ZSjx-~21 SDZ m41i. a C. ~. l~ask~til - $er-ior Driliin$ Enffii~ear EP Explaratian (Alas&a) Zs-c. P. 0. Bow 196612" _ ,_ _ _ _ , Anchorage, A~. 99Si9-~66t2 ~ Dear Mr. Maekellt We ~avs rae+ei~rwed yau~x aarre+~poader~ae dated De~t+~~b~tr 53. 190 ~ rags~esling a spacing e~cception for the Radiaott ~-25/M-27 $DI a+~31. ~a pragassd, the cae~l+~~ee~ eel ail be crgen to the Endicott Foal ~rithin $1i feat of the 1~-2~M~-25 a+e1.1 ~ a i~ prdpaae~ batte~m-hc~le~ laeativn 4195 .feat f'~a~ na~th li~ta anal .4044 feet fros-..th~ east line of section 32, TI2~, R11~ tiaat Meridian., ~`he Cest~3ssian has deter~ainad pl.acesent of th+t rorel2 will net promote ~-acte, xll aahaaee recovery and hereby approro-ea the drilling of thee: Rndtatt 3-25/M~21 l~fhZ ~t+ell as propaeed purausat to gale 3 of Cax~a-ervatian Order lip. ..202: $3,n~}cerely. Ruse~:1T A. Da~glae . Cs~~issioner $~ ARDRR OF y8L- COMMZSSZOg y S ~ i t p i~a~SS ~ ~{~ Q~iC1 1~S ~iL1t?'~ 9 ~'~~ ~ ~ ~~~ '~ ~-~uuo~ f ;a c~x~ ~~ •u~+~~~.~~~cs ~;~~~ a~a~ ~srsn xo ~x~ t~q ~zauu~ ~~~~ ~ ~~ ~ p~-~md~~P ~'4 tT~ pus '~~Q'~5'£~ ~~ f3~~~gr-~ ~ ~run.~,~.~ '~~~-~t m~o~ uQ~~~~ ~ uo~~~~,se~ #' Pub I~© ~'~'~~ ua ~~~,~uon p~~xod~,~ ~"~ . DTs `sI9:'~~~ad x~-n~u~c{a trn~~u~a ~ o~ ~d~~ ~q '~~ ~u~ag~3 sib ~~ ~rcx~~~s~pa~n ~~ ~~ •g~~r; ~ ~~ Z~~un ~nu~~uo~ pus 466I `~~ xegms~©~ ~nc~-q~ ae uc3 x~~~a a~ ~~P~~,~~ ~-~ ~u~~~~y 's~d~~ 3a ~~~~d exs~3__~t~~~8~ p~asu~~' :~q~ ~-as~q~ P'~ ~~Ao ss~ ° 3~~I S~ o~ do ~tx~a~~,~ s~-~c~~.d~d~r ~q~rsst~ pue •~5~~~~s~~u ~s -uc-~~sxado us ~q a~ ~s~ ~,~~, ~~~a'~~~PP~ ~q~ ~~~ ud~~s~ ;~ ~~ ` ~e axsT~ ~~,~ 3n ~u~~~s~~ ~~uss~acct~~ad ~u~~cnp ~s~ ~-~gl~ cad -~seusdd~- ~3u~~~snb~a t~bbt ~ a~ga~~~p 30 ~~-~~~°~ ,z~w1 p~n~~~ea ~~~~ ~M s ~vtds~ ' ~3*t ~.~~~, ~u~ t~~t~~I~`? ac~y~~rxotd~ d~ ~s~s~~~ a~s~n~~~ '~ ~t~u~ur~~~~ug i i ~~ ~zs~~ ts~'t~~F'P~l ~4~ ~~r~-ne~ s s2i (~b6t ' S x~no~ ~~~L•9t~ 4~L46} Rod ' ~d~~~~ .~ .. '~e~.+~ca~~' t9t~'~) X76-7.$42 ~av +~~ , 199 A. ~?~i N I S"~~~T Z V AF F~t4AL ~+~. 2t12.~ Rer Spe~cn~ ex~eptEan faz Bi~deott 3_2~'/~-~2 ~~~ ~wa~3l. ~ R Ms.ake~. ~enigr A~cilling En~~.neez EP ~xp ].c~r~ttic-n : tAl~~,a) ~n~ F t? So~c ~.966I2 Aneho:r~~e, Aid 99519•bB12 ~~`~` I~a~ke114 ~e have recaiv~d your r~c~~ra~pondet~~~ dat+~d. t}~~~b~r ~4, 1990 requesting a pacing +sxc®pt~.+~n. fmr tie 'F,dcott 3-29JJ-32 SItI w~el~.. As prQpr~ee~d, the ~cmtp~+~t~+~ o~ll. Ki.TI b~ apen tee the R~tdi~ett Fc~c-2 within ~fl2 feet ~~' the -1S~1I-33 ~~i1 at a prc~pv~,~c~ bate-hale ~.QCatc~zi 193 feet ~~c~a the ec+v~th l.in~ snd 4596 ~'e~t dram the ~~~t line of 9ec~iv~ `4 '~c,~hip I1 N©r~h, Rsn~+~ 17 East, U~i~~'M~ridisn, The C 3,s~~,az~ has deee ned pl~.c nt a~ the well c~11 nest prvmot+s r~+~st~, xi7.1 entice rec©v~rgr, axed 1~ereby gpprcrv+~s the ~rill~.~g o~ tha de+~tt ~-~9/~'~-~2 I I1; ~.s prt~pes~c~ puxauan~t ~o Rul~+ 3 of ~nsarvaticm order Igo. ~~. ~•.. ~...~. ~ _, w ,,,~.,,.,,~;,,; ~ltViC~ '~. ,JQhZ1 Atl t"tl~i ~ 8 ~ Oi1@'~--- BY QRI~ER ~~' C ESI4i~ d Tf t R.A73 f ~ . AAZ d I, i F ~ {9a7} ~-7542 Jule I6, 199{f A~M~P~ Z~T~AT IVE APB" ®VA~. Nt?. 2x2.8 R~-~ ~.aqua~t fear additional flare vc~1 .~ndicc~tt Field Production ~atiliti~s Stev~ca ~ Taglor, i~r 8nvironmental & regulatory Affaire ~P gagloration {A1aak+4) Inc. P 4 E~ax 19562 Anchorage, ~tI~~-~~612 Dear`Mr TePloro We have receivacd gour l,att4r of ~u1p x6, 199 tagt~sting approval to flare gs-s dining ehv~tdo~a and atart~p vi the ~ndic4tt Field grcr~lucton faciliti+~~ {88P~`y . x, ~I The C iss®n finds t~ha a~3d~tional f3,ara has to' ba `ern o era~ional geca,~aity, and hereby aggravee f7.~r~.ng up to ~~ M~'iC~' of gas over and above the designated safety flaw ghat ©f BFPF. Teatimg is scheduled to occur om or`.about:- Aust 1, 1994 and ezc~ntinue until ~€~rk is +~ late. ~.t i~ vuder,~to~-d that gas flaring mill b+~ 1~ept to a ~9.n ~ahanevar gvssible, antl all v+~l ~t .1~: ba r~portad ar~nth~.y~ on Alas&a Ql snd f3as Canearvat~.on-~ asivn forte 1t3-422. All 'gas preduced in e~o+~ss Qf the 4a0 M~~'JD safety flare pilot. wo3.u~e is sub,#aNcf to AS 43.5~~2a, atad ~rl~ be ,dieps+sad of i~ a .safe manner by flaring or used for l+se.+~~t satic. 3incaral ti .. Lcat~ia ~ ith saiouar BX t~RAE~ QF "~ Ct3Igg It? ,gym/3.AA2Q2 e s Pais Doge -_ BP ; Teleea y I~t~. Pap 23 , 199A AD~ZN I ~TRAT I VE A1~PRQ'~AL N4 ~}'~ R~ a F~p~cing exesrp~tf:an fob Endicott ' 3=29th-32., SCI Drell. ~, M E Miller ~radicott Lead Engx ~P Ezpl®~ation (~ileaka} Inc P _t3 Aar 196612 Ariehara~e, AK 99319-661..2. ~ Dear fir Miller a ~, ~ We have reaceived your ~:~rxespande~ice dated Map ~1 ~ 19913 r~squest- ing a spacing +~xx.c~eptican £~a~c the Endicott 3~29I3-32 ~~I well... ~s ~ pxcsp©sed, the crsspl~ted ill poll ~~ op~~ t~- the Endi~~tt Paol ~aehir- 91~ feet of the -~~,5/~-~3 ~va1.2 at a~ prap~~®d bc,ttc~~-holy location, 94d feet f~rm~ the south line ~~td 252k fe~~st ~ran~ the crest line a~ 8~ctic~n 4, Tc~nship 11 i~arth, Range 17 fast of the U~aiat M~ridi~n. The C iesc-n has ~tstexmined plat t o~ .the rre~.l ~-I1 txat prc~ote ataste. ~ri.ll hanca ~recaez~y~, and ~~xeb~ ~p~prpves tha drlli~E ~~ th+s_ EnBieQtt• 3•~'~I1-~2 St3I ~sll es ~~ccap~s+~d pursuant to' ~uls 3 cif C~xn-ae~vat~.cm fides Ns~, 2fl2." Sincerelq, ~~ . .~ ~Tlt1i~ ~± with ~ s s i©Iler BY €JR~LIt {~~` T~I$ CQw2+~fIS~ION s3 {:~ AA2{~ 2 _- T~aleaog~ Na, {9a7> 276-742 March 7, 199th A~M~:~ Z~TRA~IY~ A~'P~,flV,AL ~. 202.6 f, ~e a ` ~pacia~ e~c+cep~ion for Endicott 2-~/L-16 r~ra11. ~ ~ ~ t~ille~r Endicott Lead 8ngg_ ~ EP Explara~Cion {~lesi~a} Inc ~ P ~ Bay 19.561 f 'Anehcxage, A1~ 945I9-5b12 ~. near k~r M12er s We have r+~c~tved yon eorr~sp~den~e dated March 2, 1~39t1 requcstinE a..apacinE ea~ce~tic~x~ for the Endicott 2-18fL~I6 MCI ~~tl.l Apt grapa~~d, the ec~-plet~cd veil w~.ll he ap~n to the ~ E~adicatt Foal ~tithin ?~t3 fe+et- of the ~-16JM-lb r~x well. a.t ~. prop~~~d be~~t~m~ho1~+~ 1oc+~tion X277 feet from the ne~rttt 13.ne and 14Q fe~~ frc~ t~s ea~c lie of S~-~t~cs~ ~ ~'o~nsh.i.p 12 Nar~h, E,~ ,fie l6 Ease t~£ tt~e ~3miat Merdiaai 'i'he Ccxi,~~ion hay d~ete~mined p1ac+~+en of the w~:tl. ~ri1.I nQt ~promc~te ~~~~~ r~il~. ent~e ree~av~ry- :and h+~rebY apgraves the drillinE of a Endicott 2-38/L..yS 3~PZ ~reY.l a~ grQpos~d pur,euant ' to Rule of Consea~vatian ~Izder Rio, 242. ~ine~~rel~y # Lennie ~ ~m Ca~amissianer ~'~ tJEUER t3~ CC~1~iZ~SIU ~o /3.A~l~t}2 ..,~ .. . t :~ ;, .1 . {9tI/~~276~?~42 ~. t~ctober 26, 198$ ;~ , ADM;IN i STg.AT'I VE A.; R4V~ N0, 2Q2.5 -. ... ;~~ . _o _ ~~ a Lndicatt Pressure Monitoring Key e and ~a~-4i1 Contact Monitor Kep We1I Pxegrams _~.; ~,. _ _ _, __ J W Buck+~e St~ndsrd Aiaska Production Co ;; P 0 Box 1~~12 Anchvrsge ~K 99519-661 'r 'Dear Mr 13uckee: '~ We have recoived ~QUr ecsrreapond+~nce dated ~-ctc~her 13, 1.988 requesting approval of Endicott Pressures Monitoring Kerr dell and Gsa-Oil Contact Monitor Eep 6~e11 Pragra~s , Thew prca8,zau~ ' co~a-ply ~ with Rules 6f~? Viand 9{c) a~ Conservation Order CCO) No. 2z "'fcar ~ the Endicott ©i3. Pool. The Cvx~ission has reve~ad the Presuze Monitoring Key W+s11 Program .and her®by approve, it as prapased. RequiremeMts oi- CC 2t~2 Ru~.e b t o) ,ire superseded by the prcapoe~ed program. The Cam~issian h+es ravi~a~red the Ge-a--Oil Cantaet Monitor Rap Well Program and hereby approves it as proposed. Requf,re~ezzts a~ CO 242 Rule 9{b)'are superseded by the prapasedprogr~m, The Ca~aissiom is encouraged that a seviex is scheduled for _ `September, 1989 t and requests that this bs spade an aa~nual event, .The Go .aeon elan requests that a r~ritten s rp o~ th+e s programs' evaluatian~e be aubmitted at the annu~l'te~eeting. If you hays rant' qu+sstior~s regarding` this Iette=` please callus. .:, Sincxezely -~ __~:r a~ L©nnie i Co isieaner ~ BY t~~gR t3P 'THE COI~IISSI4N ., , ..~ . joJ3.AA2~2 >, ~, August I8, 19138 Telecopy Teo. {907) Z76-7542 AT~~IiIrl1STE.AT TVE APPRdVAZ ®.102. ka: Z~~crease safety fls.re for than Er~.dicatt Fuld, Endicott Oil Pool. production f~.cilities. A tiavies Endicott: lieu Pl~.nning Sts.ndard Alaska Pzoductior~ Company P U Boy. 29b612 Anchorage, AK 99,519--~~~.2 bear fir T~svies ire have received your letter of August 12, 198 requestiaig an increased bafety flare volume for the Endicott Field, Endicott OZ Pool product:iori facilities. T3ata submitted to the Cottunission at: an August 8, 19d8 ~reetit2g with SAPC representatives support increasing the curre~zt Endicott safety Flare volume to provide fs.cilty safety when the second ca~mpressor train is activated. The Coz~zssion hereby sets the safety fls.re far the Endicott k"field, End~.cott tail Pool production faci~.ities at 4p0 I~SC~' per d.ay. The daily average rate shall. be calculated on a monthly bs.sis. This appravs:l supersedes Administrative Approval No. LOZ.~. Sincerely, ; ,,~,~: ~ X Lonnie C Su,ith Co~mnis s inner BY OkI3ER OF TIfE CQ rt~IISST4N ,~oI3.AA202 September I7, l9$7 Telecopy No. (907} 276-7542 A~MY~ Z S-TR'`~TIVE .APPROVAL N0. 202.3 Res The applicatian of Standard A7.as~~t Production Company, operator of the Endicott Field, to: qualify an additional grade ofcasing ~orruse as surface casing in the Endicott Field. S Alan Division Drilling Engineer Standard Alaska ~roductian Company, P Q Bow 196612 Anchorage, AK ~~~~.~-•~~}~~ Dear Mr Allsn: Your application was reetaived on August 17, 1887 requesting that an additional grade of pipe be approved for use as surface easing in the Endicott Field. In support of that re€~uest, you presented chemical composition, strnctur~l data, and stresslstrain curves f©r 13-3J8" 68 ~lblft PI'T'-8€1C ERW buttress casing. The Cc~~ssian hs~ carefully revie~red-all of the data available, and finds that the evdehce aubmitt+ed in' ~.ccordance with. Rule 4, paragraph.:{e)_of Conservation Urder No. 2Q2 indicates this casing , grade meets the regt~iremen~ts ©f Rule 4, paragraph (c), of said order. ~~ Pursuant to these. reQtxire~ient~, the Cot~ission approves the use of 13-3/8" 681b1ft NT-$~CYAE ERW buttress pipe for surface casting in the Endic©tt Field. ~~' 1nCE'.re~.ya l '' ~ J Lonnie C Sffiith Commissioner BY ORDER t3F ~ Cf~fISSIOPI .- ~oJ3.AA202 ~ ~- February 20, 19$7 Telecopy No. (907> 276-7542 ADMINI STRATIVFr APPROVAL N0. 2©2,2 Re: Establish safety flare far the Endicott Field, Endicott Oil Pool production facilities. Mr. A. B. Huxley tanager, Development Planning - Endicott Standard Alaska Production Company P. 0. Box 196612 Anchorage, AK 99519-6612 Dear NIr. Huxley: We have received your letter of February 13, 19$7 requesting a safety flare volume for the Endicott Field, Endicott Oil Pool production facilities. Gas flared in maintaining a safety flare is an operational necessity at production and related facilities to prevent an explosive mixture from occurring, and to ignite any hydrocarbons that are vented during emergencies or operational upsets to avoid the risk of loss of life and property due to explosion and fire from hydrocarbon accumulation. The Commission hereby sets the safety flare for the Fndicvtt Field, Endicott Oil Pool production .facilities at 125 t~SCF per day. The daily average rate shall be calculated on a monthly basis. In regard to your request for emergency flaring authorization, the Commission feels our regulations, specifically 20 AAC 25.235, adequately provide emergency flaring relief, Therefore, the Commission will take no further action regarding this request. Sincerely ~_-; t~ ~'~ _(a ~ Lonnie C. Smith Commissioner BY ORDER OF THE COI~INiISSION joJ3.A.A202 -.. January 3Q, 1987 Telecopg ~o. t9Q7) 276-7542 A D:M Z N I~ fi R~ T I V E A P P R, O V A L N-O. 202,1 Re: Endicott Faciltl.es Sta=tup Flaring Nr. D. B. Huxley . Manager, Development Planning - Endicott Standard Alaska Production Company P. 0, Box 19b512 Anchorage, AK 99519-5612 Dear Mr. Huxley: We have received your letter of January 26, 197 requesting approval. to flare gas during commissioning and startup of the Endicott Field production facilities. The Commission recognizes that flaring ©f gas during commission. and startup of the Endicot Field production facilities is an operational necessaty, Therefore, the Commission hereby approves` flaring of up to 1,5 A3MMSCF of gas during startup of said -facilities. Commencement of flaring wil3. be in Late 1987. The Commission requests notification nne week prior to commencement of flaring. It is_understood that efforts wi11 be made to keep flare volume at a minimum, and ail gas flared under this authorization be metered ands subject to AS 43.55.020(e}, S 1TiCerEly Lonnie C. Smith Commissioner_ BY ORI?LR OF THE COMMISSION jo/3.AA2Q2.3 ~ 51 f ~~ • R. L. Skillern Senior Landman -Alaska BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO Box 196612 Anchorage, AK 99519-6612 (907) 564-5111 Phone: (9071564-5567 Fax: (907) 564-4264 - Email SkilleRL~bp.com November 20th, 2008 Web: www.bp.com Mr. Kevin Banks, Acting Director Division of Oil & Gas State of Alaska, Dept. of Natural Resources 550 West 7th Avenue, Suite 800 Anchorage, AK 99501-3560 Mr. John Norman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Request for Surface Commingling of Production for Well 2-30B/M E-01 Gentlemen, In accordance with 20 AAC 25.215, BP as Operator of the Duck Island Unit and sole Working Interest Owner of lease ADL 34633 (Tract 13) hereby requests permission for surface commingling of production from Well 2-30B/ME-01 with production from the ,Eider, Sag Delta North, and Endicott Oil Pools. The Operator proposes the following methodology for tracking production from Well 2-30B/ME-01. • Production from Well 2-30B/ME-01 will be allocated on a daily basis using the same methodology employed for wells in the Eider Oil Pool (Conservation Order No. 449) and will be tracked through BP's production tracking system. Allocations will be based on well tests as described below. • VVeii 2-306/ME-01 will be tested a minimum of two times per month during periods when the well is on production. The meter allocation factor for Well 2-30B/ME-01 will be fixed at 1.0 ~.ti x - • Allocated data will be reported monthly to the DNR using form 10-405 as required by~ 20 AAC 25.230. This methodology for • Mr. Kevin Banks, Acting Director Division of Oil & Gas Mr. John Norman Alaska Oil and Gas Conservation Commission November 20th, 2008 Page 2 allocation and reporting will continue until final determination of the Producing Area for Well 2-30B/ME-01. Should you have any questions, please contact John Garing at (907) 564-5167. Since rely, ~ ~ y r R.L. Skillern • cc: John Garing Endicott Files • Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography CEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99502 Anchorage, AK 99503 Anchorage, AK 99503 Baker Oil Tools Ivan Gillian Jill Schneider 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 US Geological Survey Anchorage, AK 99503 Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K&K Recyciing Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 ~'%~ i~2?i~ 1 • Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, January 23, 2009 11:30 AM Subject: co202-043, co275-001 and co449-001 Endicott Attachments: co202-043, co275-001, co449-001.pdf BCC;Aleutians East Borough; Anna Raff; Barbara F Fullmer; bbritch; Bill Walker; Brad McKim; Brandon Gagnon; Brian Gillespie; Brit Lively; Bruce Webb; buonoje; Cammy Taylor; Cande.Brandow; carol smyth; Cary Carrigan; caunderwood@marathonoil.com; Charles O'Donnell; Chris Gay; Cliff Posey; Dan Bross; dapa; Daryl J. Kleppin; David Brown; David Gorney; David Hall; David House; David L Boelens; David Steingreaber; ddonkel; Deborah Jones; doug_schultze; Eric Lidji ;Evan Harness; eyancy; foms2@mtaonline.net; Francis S. Sommer; Fred Steece; Garland Robinson; Gary Laughlin; Gary Rogers; Gary Schultz; ghammons; Gordon Pospisil; Gregg Nady; gspfoff; Hank Alford; Harry Engel; Havelock, Brian E (DNR); jah; James Scherr; Janet D. Platt; jejones; Jerry McCutcheon; Jim Arlington; Jim White; Jim Winegarner; Joe Nicks; John Garing; John S. Haworth; John Spain; John Tower; John W Katz; johnny.aiken@north-slope.org; Jon Goltz; Julie Houle; Kari Moriarty; Kaynell Zeman; Keith Wiles; keelson@petroleumnews.com; Krissell Crandall; Kristin Dirks; Laura Silliphant; Lynnda Kahn; mail=akpratts@acsalaska.net; mail=fours@mtaonline.net; Marilyn Crockett; Mark Dalton; Mark Hanley; Mark Kovac; Mark P. Worcester; Marguerite kremer; Matt Rader; Melanie Brown; Mike Bill; Mike Jacobs; Mike Mason; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; Nick W. Glover; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; Patty Alfaro; Paul Decker; Paul Winslow; Pierce, Sandra M (DNR); Randall Kanady; Randy L. Skillern; rcrotty; Rice, Cody J (DNR); rmclean; Rob McWhorter ; rob.g.dragnich@exxonmobil.com; Robert Campbell; Robert Fowler; Robert Province; Roger Belman; Rudy Brueggeman; Scott Cranswick; Shannon Donnelly; Sharmaine Copeland; Sondra Stewman; Sonja Frankllin; Stan Porhola; stanekj; Steve Lambert; Steve Moothart; Steven R. Rossberg; tablerk; Tamera Sheffield; Temple Davidson; Terrie Hubble; Tim Lawlor; Todd Durkee; Tony Hopfinger; trmjrl; Von Gemmingen, Scott E (DOR); Walter Featherly; Walter Quay; Wayne Rancier; Aaron Gluzman; Dale Hoffman; Fridiric Grenier; Gary Orr; Joe Longo; Lamont Frazer; Marc Kuck; Mary Aschoff; Maurizio Grandi; P Bates; Richard Garrard; Sandra Lemke; Scott Nash; Steve Virant; Tom Gennings; Willem Vollenbrock; William Van Dyke; Woolf, Wendy C (DNR); Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments:co202-043, co275-001, co449-OOl.pdf; Jody J. Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 1/23/2009 X50 by ~ March 10, 2003 Mr. Steve Davies Alaska Oil and gas Conservation .Commission 333 W 7'h Ave., Suite 100 Anchorage, AK 99501 RE: Endicott We112-28B/0-19 Spacing Variance Permit No. 203-006, API 50-029-21847-02 Dear Steve: BP Exploration (Alaskallnc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Enclosed please find a map (Figure 1), log cross-section (Figure 2), and spreadsheet (Figure 3) showing the location of proposed well Endicott well 2-28B/0-19 which we plan to drill and complete within 1000 ft. of existing injection well 1-05/0-20. Proposed well 2-286/0-19 target (T2) at the top of Zone 1 will be 960 ft. horizontally and 490 ft. vertically from the Fi perforations in well 1-05/0-20. Well 1-05/0-20 is a gas injector completed in zones Fi, 3A and upper 2B; well 2-286/0-19 is planned as a 2B, 2A producer. Since the two wells will be completed in different zones they will not compete for the same oil. BPX (Alaska) Inc. requests administrative approval to waive spacing requirements stipulated in the Endicott Pool Rules Conservation Order 202 Rule 3 and allow well 2- 286/0-19 to be drilled and completed within 1000 feet of existing well 1-05/0-20. Please contact me at 564-4531 if you wish to discuss this proposal. Sincerely, _. ~~~~~> Katie Nitzberg Endicott Staff Geologist BP Exploration V ~~ ~,~aR ~ ~ ~QO~ ~~ ~i ~ uas Cads. Cammi~n T2 location 260,689 5,982,496 with 1000' circle Perforations shown in green ~Z- v w I O '~ I o~~ 0 ~, 0 Y I I N rn 0 i T n~ W 3 ~ o pp p pp pp O O O O O O O O O O C N O N D N O O N O N O N C O N O h O O O O h O ~ N N M M Y YYYY Y Y m N '~ b h ~ t0 0~ ~ O O O O O _O O O O O O O O O_ O I m I T ~ T ~ I I ~ T I I I I I I I I I 1 I 1 I >°. .nl } ~ c. ., ~ -. ~ 0. .~ ~. L ~, 1 ' I ~ . ~ ; %"/~ ~ .m« I ~ ~ , y ~ ~,- ; ' c G ' )~ ~y '//~ / N a~ ~~~, ~. .~° .Q .~ N N ~ o . ~ ~ ~ Y o~ U ~ I IV~ . J ~. .`~ a~ o a .~ ~ .~% ~e. /` r' / • ~`.~ II .~~~ ~~ ~e+~ , ' .I ~ F+P` .~ Q~ /. :~ ~. . O « e « O e ^~ i~ e ~A~` W Q ~~ p N ~~ P r 1 t ~2 zl Spacing Variance for 2-286/0-19 1-05/0-20 2-286/0-19 Lateral distance (ft.) Top Fi perfs Zone 1(T2 target) X 261, 643 260, 689 961 Y 5, 982, 382 5, 982, 496 Z 9600' ss 10090' ss 3A/26perfs at 10662 Zone 1 T2 target X 261, 773 260, 689 1, 092 Y 5,982,360 5,982,496 Top Fi perfs Top Fi X 261,643 260,326 1,318 Y 5,982,382 5,982,433 Figure 3 X49 by ~ February 19, 2003 Mr. Steve Davies Alaska Oil and gas Conservation Commission 333 W 7th Ave., Suite 100 Anchorage, AK 99501 RE: Endicott Well 3-17E/K-30 Spacing Variance Permit No. 202-247, API 50-029-21946-05 Dear Steve: BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (9071561-5111 Enclosed please find a map (Figure 1) and log cross-section (Figure 2) showing the location of proposed well Endicott well 3-17E/K-30 which we plan to drill and complete within 1000 ft. of existing production well 3-07A/L-29. These two wells are on opposite sides of a sealing fault and therefore will not compete for the same oil. The sealing nature of the fault between 3-17E/K-30 and 3-07A/L-29 is documented in the SPE Paper #21760 Design and Implementation of the First Arctic Offshore Waterflood, Endicott Field Alaska by Adamson, G.R.; H.L. Hellman and R.R. Metzger (1991) (Attachment A). On page 3 of the document it states "Six months after production start-up, static pressures data showed an anomalous pressure differential near the Midfield Fault system. Average pressures for subzones 26 and 2A showed a 150-200 psia differential across the fault, clear proof of limited transmissibility across the fault system." The next paragraph states "The discovery that the Midfield Fault was sealing necessitated treating the reservoirs on each side of the fault system separately." BPX (Alaska) Inc. requests administrative approval to waive spacing requirements stipulated in the Endicott Pool Rules Conservation Order 202 Rule 3 and allow well 3- 17E/K-30 to be drilled and completed within 1000 feet of existing well 3-07A/L-29. Please contact me at 564-4531 if you wish to discuss this proposal. Sincerely, Katie Nitzberg Figure 1 -x-48 b ~ p BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 19, 2003 Mr. Steve Davies Alaska Oil and gas Conservation Commission ~ ~~~ ~ ~''~' t 333 W 7th Ave., Suite 100 ~ ~° Anchorage, AK 99501 ~-j ,,,§n~ k~~~~x RE: Endicott Well 4-10A/L-28 Spacing Variance <~ ; `.:,~;;v;,, ,~°ra-wx ~;~ Permit No. 202-238, AP150-029-22464-01 f -' "~`" Dear Steve: Enclosed please find a map (Figure 1) and log cross-section (Figure 2) showing the Endicott well 4-10A/L-28 which we plan to perforate within 1000 ft. of existing production well 3-07A/L-29. These two wells are on opposite sides of a sealing fault and therefore will not compete for the same oil. The sealing nature of the fault between 4-10A/L-28 and 3-07A/L-29 is documented in the SPE Paper #21760 Design and Implementation of the First Arctic Offshore Waterflood, Endicott Field Alaska by Adamson, G.R.; H.L. Hellman and R.R. Metzger (1991) (Attachment A). On page 3 of the document it states "Six months after production start- up, static pressures data showed an anomalous pressure differential near the Midfield Fault system. Average pressures for subzones 2B and 2A showed a 150-200 psia differential across the fault, clear proof of limited transmissibility across the fault system." The next paragraph states "The discovery that the Midfield Fault was sealing necessitated treating the reservoirs on each side of the fault system separately." BPX (Alaska) Inc. requests administrative approval to waive spacing requirements stipulated in the Endicott Pool Rules Conservation Order 202 Rule 3 and allow well 4- 10A/L-28 to be perforated within 1000 feet of existing well 3-07A/L-29. Initial planning for drilling of this well inadvertently overlooked the spacing requirements under the Endicott Pool Rules. Please contact me at 564-4531 if you wish to discuss this proposal. Sincerely, Katie Nitzberg • I N 3-17E K-30 S Plan ed Well 3-17 J-30 _ Midfield Fpult 3-07A L-29 -9800 -9800 -9850 -9850 K28 (TR ) ..... .................................... .......... . -9900 -9900 K2B (TRj .................. . -9950 K2M -9950 K2M K~'A K2A -10000 -10000 -10050 -,0050 -10,00 -,0,00 _,0,5D - Figure 2 -,D,50 ~ ~~ - GAPI 150 0 _________= _= -8800 BHR2 =______ .::::.::: ~iV ______________ . K2B -- ...... 2600E __ ::::::::::::: _- ................ -1 K2A _--- ......:::::::: 32A2 _______________ _ _ .:::..::::::: -101 S2A1 =_ .::::::::::::: ~ ~ ;~WIRE_3_07.CR_DENS_, ' ~ Gnat t so ______--- ...:::: -0800 c =. =. -=c==== ":: 8800 LCU === ...:::::::::: K2M ===- ..::.:::::: ______ ...:..:..:: ........ -10000 K2A ---~ =_- S2A2 :::::::::::::: 32A1 260038 K1 -10100 SPE ;~ i ~ 6 0 Sopety of Peuatea+n Ergrtt:e~s .PE 21760 lesign and implementation of the First Arctic Offshore Waterflood, :ndicott Field, Alaska i.R. Adamson, H.L. Hellman, and R.R. Metzger, BP Exploration {Alaska) Inc. PE Members 1pyrlght 1991, Society of Petroleum Engineera Inc. iia paper wss proparad for presentation a the Western Regional Meeting held in tong Beach, CaNtornia, Marcn 20-22, 199t. tie psper was selected for presentation by an SPE Program Committee fotbwing review of intormatton cantainsd in an abstract fubmitted by the aulhOrts). Contents of the paper, preaented, hsve not been reviewed by the Sceiety of PetroNum Engineers and are serbjoN to correction by the author(s). The material, as presentee, does not rreCessarity rstlett +Y position of the Society of Petroleum Engineers, its otrieara, or msmbsn. Papero presented a SPE meetings an subject to publication rovtew by Editorial Committees of the Society Petroleum Engineer. Permieaion to copy ro restricted to an abmact of not mar than 900 words. t9ustrations may not ba copied. Tns abstract ahoub eonto,n conapti:uous acknowtedgmem where e~A by whom 1M paper to presented. Write Publtcationa Manager, SPE, P.O. Box 833896. Richareson, TX 760tt1~3838. Telex, 730989 SPEDAt. fhe Endicott Fieid is the first Arctic offshore producing oil field. Early reservoir studies showed that optimum ecovery would require start-up of waterflooding within the first fora years of production. This paper describes the engineering and geological work done to implement and optimize the Endicott Field waterflood. i'he reservoir at Endicott Field is contained within the Mississippian Kekiktuk Formation. These multistory fluvial Sandstones are characterized by wide variations !n rock properties. Thick areally extensive shales combined with Sealing antra-reservoir faults, s9rve to subdivide the field nto seven distinct reservoir management sub-zones. . The design and implementation of this waterflood project extensively used simulation studies. These stu~:iies showed that waterflooding would nearly double the recovery and there were significant benefits for returning the field to original pressure. Simulation models optimized aoth the number and placement of production and injection wells. Endicott Fieid is located two miles offshore in the Arctic Ocean, about 8 miles (12.8 km) east of Prudhee Bay Fieid. To date, 74 wells have been drilled from two man-made gravel islands, both constructed in 14 feet (4.3 m) of water. The main production island (MPI) contains production facilities and about one-half of the wells. The remaining wells have been drilled from the satellite drilling island (8DI). The field produces from the Mississippian Kekiktuk Formation. Current estimates of total hydrocarbon volumes are 1.1 billion barrels (175X106 m3) of oil in place , 400 BCF (11X109 m3) of gas cap gas, and 800 BCF (22X108 m3) of solution gas. Production start-up began in October of 1987, water injection began in February, 1988 with the field wide injection project completed by mid 1990. To date, the field has produced over 100 MM80 (15.9X106 m3) at an average daily offtake rate of 100,000 barrels of oil per day (15900 m3/d). Reservoir pressure is maintained to optimize field recovery through gas reinjection into the original gas Asp and water injection. The first production facility sealift included waterfiood facilities. This enabled a pilot program to be implemented within five months after production start-up to shake down facilities, determine well infectivity and obtain early waterflood performance data. References and illustrations at end of paper. The Kekiktuk Formation is the earliest member of the Mississippian aged Endicott Group and unconformably rest3 on older upper Devonian deformed metasedimentary basements rocks. Conformably overlying the Endicott 103 2 SPE ~ ~ ~ 6 ~ u~sIGN AND IMPLEMENTATION OF THE F1R~ SPE 21760 ARCTIC OFFSHORE WATERFLOOD,ENDICOTT FIELD, ALASKA Group is the transgressive marine Itkytiarlak Formation. (Figure 1). further subdivided by the presence of a regionally extensive correlative lacustrine shale sequence. The tectonic history for the Endicott Group is complex. Numerous unconformities, syndepositional faulting during the Mississlpplan, and post-Mississippian tectonic overprints (wrenching and reactivation of earlier tectonic elements) occur associated with the opening of the Canada Basin to present day NoRh. Deposition of the Kekiktuk sands occurred within depocenters controlled by uplifted basement terrains during Ellesmerian time. Gradually, southerly flowing fluvial systems developed eroding basement highlands. Braided and meandering streams deposited their bed loads over pre-Kekiktuk swamplands and tow-tying basement terrain. Structure (Try The Endicott Field is a combined stratigraphic/structural trap. Hydrocarbons are accumulated in a southwesterly dipping fault block bound on three sides by major normal faults (Figure 2). Structural dip closure occurs to the southeast. On the northeast, the Tigvariak fault juxtaposes older basement rock against Kekiktuk sands. To the southeast, the Mikkelsen Bay Fault juxtaposes younger KayaWltkyliariak sediments with the reservoir. The Niakuk Fault, a major North Slope tectonic feature, juxtaposes Triassic and Cretaceous sediments against the Kekiktuk. Seal is formed both by the conformably overlying marine Itkyliariak and by regionally continuous, lower Cretaceous shales which unconformably overly tilted Kekiktuk antiformal fault btocxs. Hydrocarbons are thought to have been predominantly sourced trim the overlying Cretaceous shates.l Several intrareservoir normal faults have been identified. These faults directly affect waterflood, field development, and offtake planning and will be further discussed in a later section. Within the Endicott Field, three major lithostratigraphic units are defined within the Kekiktuk Formation. Figure 3 shows the average zonal rock properties. The lowermost interval, Zane 1, is mainly comprised of shale and coal swamp sediments with minor poor-reservoir quality sands. Zone 1 is "capped" by a major correlative coal. Zone 2 sands are predominantly medium to coarse grained and often conglomeratic, interpreted as braided stream deposits. T;iese sands comprise some of the highest grade reservoir rocks found on the North Slope with enhanced secondary porosity as high as 28% and permeabilities often as high as several darcies. Zone 2 is Zone 3, the uppermost part of the reservoir is composed of stacked fluvial channel sand sequences with carbonaceous mudstones and tine sandsJsllts deposited in interchannel floodplanes. Within Zone 3, several regionally extensive and correlative coals, shales, and shaley sequences (38) further serve to subdivide the reservoir into vertically isolated hydraultc units. Elgl~;z In descending order, the fluids at Endicott consist of a gas cap, oil leg, "intermediate" aquifer, tar mat, and regional aquifer (Figure 1). The oil column Is about 340' thick, bound by a planer gas-oil-contact at 9855' (3004 m) TVDSS and an ell-intermediate aquifer contact at 10,195' (3107 m) TVDSS. The presence of an greatly extensive undulating tar mat separating the intermediate and regional aquifers is of major importance in its' etfect on waterflood planning and injection well placement. The tar mat, combined with the presence of major field bounding faults, effectively isolates the regional aquifer below 10,400' (3179 m) TVDSS from providing pressure support. Complexities resulting from the combined effects of vertically segregated subreservoirs, areal differences in zonal rock properties, structure, and tar presence, led early-on to the realization that optimum field planning and development needed a detailed geologic model. Based on previous experience gained at Prudhoe Bay Field, reservoir description sensitivities such as sand continuity, shale distributions, and faulting were identified as having significant impact on partial and full-field simulators, well completioc3, and reservoir management strategy. A focused effort was undertaken to acquire, store, and interpret data. These data included: a 3-0 seismic survey covering fifty-five square miles (142 km2) at 110 foot (33.5 m) spacing, detailed core and lithofacies analysis from 8 wells covering all reservoir sub-zones, dipmeter analysis of cored and uncored sections, full suite resistivity and porosity open-hole logs for ail development welts, and cased hole pulsed and compensated neutron logs where necessary to confirm reservoir continuity based on gas and water movement. Pressure data to the form of build-ups, statics and open- hole repeat formation pressures were also critical in shaping a working reservoir description move!. 10a ~ ~ ~1~60 ' SPE 21760 Q. R. ADAMSON, H. L. HELLMAN, R. R. METZGER 3 The Endicott reservoir is broken by numerous intrareservoir faults of minor throw. These faults generally are subparallel to major field bounding faults. Six months after production start-up, static pressure data showed an anomalous pressure differential near the Miditeld Fault system (Figure 4). Average pressures for subzones 26 and 2A showed a 150-200 psia (1030-1380 Pa) differential across the fault, clear proof of limited transmissibility across the fault system. The lack of pressure communication is attributed to the combined effects of "smearing" of ductile beds and possible mineralization along fault planes. Poor pressure support in the SDl area is caused by limited access to the MPI gas cap across the Midfield Fault and ineffective aquifer support resulting from the presence of tar. The discovery that the Midfield Fault was sealing necessitated treating the reservoirs on each side of the fault system separately. Initially, this required reduc'ng offtake on the SDI side due to rapidly falling resen sir pressure. It was also necessary to accelerate the drilling of water injectors to provide pressure support. Distinct differences erist in depositional environment, reservoir quality, and net:gross sand ratios betv+~een sub- zones 36/3C, 3A, and 29/2A. This has led to fundamental differences in development planning for each sub-zone. Effects of structural dip, aerially continuous coais/shales (vertical segregation), and a sealing Midfield Fault have worked in concert to produce six separate main subreservoirs (Figure 5). The seventh subreservoir is the 3B/3C in the down-dip peripherial edge of the iield. In the high net:gross sand subzones 3A and 28/2A, the presence of down-dip tar and structural error were the critical risk factors in water injection well placement. Tar occluded sand porosity was observed to have little injectivity, and there was little evidence of aquifer support, indicating that communication through the tar was very low. Injection wells had to be placed to have access either to the intermediate aquifer above the tar or where no intermediate aquifer was present as near as possible to the down-dip limit of the light oil wedge (Figure 6). In the lower ~et:gross 3C sand sequence, development planning took a different approach. Although the risk of tar occurrence and structural error was still present, an added risk was the absence of reservoir quality sands. An intensive reservoir description effort was undertaken which redefined subzone 3C stratigraphy into five depositional sequences (Figure 3) with mappable channel trends. Development wells and water injectors were,driiled to achieve optimal well placement with respect to sand development. To date, static and open-hate repeat formation pressures have shown increased pressure connecttviry of these lower net:gross sands than originally expected. Pressure connectivity will lead to higher oil recovery through enhanced waterflood efficiency and potentially decrease the number of wells necessary to adequately exploit 3B/3C reserves. The development process of the Endicott Fieid has used reservoir simulation extensively. Reservoir simulation has evaluated well density, lateral weir standoff from the gas cap and aquifer, and waterflood benefits and timing. The simulation model (VIP) used for most of these studies is a four phase partial compositional program. VIP allows two gas phase compositions, although alt development simulation of the Endicott Field used the program simply as a black o~ simulator. Three types of simulation models have used: 1) full field models (FFM's), 2) partial field models of isolated reservoirs of the field (PFM's) and 3) very finely gridded generic models (mechanistic). The first FFM had coarse grids representing areas of 40 acres (16 hectares). Recent improvement in computer memory size has allowed development of a FFM with areal grids as small as 5 acres (2 hectares). These models were used to optimize facilities design, estimate total development well counts, and evaluate field wide development strategies such as waterflood benefits and timing. Full Field Models use pseudo relative permeability curves derived from fine grid cross section models. Partial Field Models have finer gridding than the Full Field Models. Areal gridding has been from 1 to 5 acres (.4 to 2 hectares). Reservoir sand sequences are modeled with 10 toot (3 m) layers at the top and bottom and enough additional layers so that a maximum layer thickness of 50 feet (15 m) is not exceeded. Reservoirs modeled using PFM's are effectively hydraulically isolated from each other and require simple boundary conditions. The small reservoir volume evaluated by these models allow fine gridding and improved detail. Mechanistic models use very fine layering and gridding to evaluate optimum pertoration placement, pulse tests, single well tracer tests, and other generic concerns. Mechanistic models impacted basic development decisions, but have had little affect on waterflood development planning. The Full Fieid and Partial Feld Models have been initialized with reservoir properties obtained from a detailed static 105 4 SpE 2176 ~ DESIGN AND IMPLEMENTATION OF THE FIRST SPE 21760 " ARCTIC OFFSHORE WATERFLOOD,ENDICOTT FIELD, ALASKA geologic model. This static model contains up-to-date reservoir geology interpretation in a digitized format. data can be extracted In any predetermined areal and vertical grid size for use in a simulation model greatly enhancing the ease of building reservoir simulation models. Early development Strategy for the Endicott Field utilized various reservoir simulation studies. Reservoir properties for these studies came from limited data obtained from exploratory and delineation well logs and cores. The most significant of these studies used a Full Field Model with a 38 x 10 x 24 grid with each areal grid representing 40 acres (16 hectares). This study used Sohio's (now 8P) 3D3P simulation program. Although the areal gridding was coarse, the layering was flue enough to allow thin (10 ft (3 m)) layers at the top of each sub-zone to account for gas underrunning shales. This model evaluated the benefits and best timing for watertlooding and calculated an increase over primary recovery between 50 and t 00%. This same study estimated that watertlooding could be delayed by as much as two years after field start-up without reducing recovery. However. it would be necessary to repressure the reservoir to avoid any bsses. Facility sizing, well spacing, ofitake rate, tubing size, and production scheduling were also evaluated with this model. After field development began, watertlood strategy was further optimized using Partial Field Models. A separate model was created for each reservoir sub-zone on Bach side of the Mid-Field Fault. These models evaluated the optimum number and location of injection wells, the best injection strategy and the benefits of any additional production wells. These partial field models showed significantly greater recovery benefits (3-6% OOIP) for repressuring the reservoir than calculated in the first Full Field Model (~1% OOIP). Another major effect on field development from the PFM studies was a reduction in the number of water injection wells. Simulation calculations showed that two injection wells on each end of the separate reservoir sub-zones yielded better recovery than three injectors spaced evenly across these reservoirs. Recovery is increased with maximum standoff between the injectors and producers. These simulation studies saved the cost of drilling three to six wells, which cost about $3.5 million each. Simulation studies have influenced other operating strategies. On the MPI side of the field, the reservoir will be depleted using a combination of watertlood and gas displacement drives. Simulation studies were very critical in determining the optimum balance between water and gas injection. Gas produced from all wells in the field must be injected into the gas cap of MPI sub-zones 3A, 28 and 2A. Studies showed that over injection of gas (i.e., injecting more gas than produced from a particular reservoir) improved recovery in the Zone 2 reservoirs but reduced recovery in the Zone 3A reservoir. These studies led to the decisbn not to Inject gas into the upper 3B and 3C reserv~alrs to leave more gas available for injection into tine Zone .: reservoirs. ~- Model initialization and history matching is a joint geological and engineering effort. TP~ese interactions are mutually beneficial. The geologists identify potential heteroger~eities that could affect how to history match a model. Conversely, the results of the modeling effort can give indications of reservoir characteristics not previously identified. Since field wide water injection was planned to start within the first two years of field production, water injection facilities were included in the production modules sealifted io Endicott from New ~•aria Louisiana arriving in August, 1987. Priority was played on commissioning of the production facilities which were completed with production starting on October 3, 1987. Commissioning of the water injection facilities followed with completion in February 1988. ejection Testing Injection tests were conducted on three wells during the summer and tall of 1y87. Injection rates into the wells were much less than predicted and a concerted effort was made to idRntify the cause. Two major factors were Identified. These were inadog~ate wellbore cleanup due to lack of production and poor oxygen scavenging of the seawater resulting in corrosion products causing plugging. Tests were suspended until the production facilities were available for high sate welt cleanup and until the water injection facilities were available to provide oxygen scavenged water. Sea water and produced water injection facilities are provided within the Endicott production facilities as seen in Figure 7. Seawater is supplied through a seawater intake system from a water depth of 14 feet (4.3 m). The intake system includes marine life screen and bypass systems to exclude marine fife from the intake. The intake water is filtered through a set of downitow graded bed filters, deareated in a gas stripping deareater and pumped to injection pressure of about 2500 psi (17X106 Pa) via a gas turbine driven centrifugal pump. Only a single train is provided with a noirinal capacity of 140 MBPD (22 300 m3Jdj. Produced water from the production train is sent through a pair of corrugated plate interceptors to remove the oil to less than 25 ppm. The produced water is then fed to a pump identical to the sea water pump. The injection 106 ~ SP.E 2160 5PE 21760 G. R. ADAMSON, H. L. HELLMAN, R. R. METZGER facilities are configured to allow either injection pump to handle sea or produced water. Because of the early infectivity problems encountered, it was decided to implement a pilot project as soon as practical in order to determine infectivity parameters, shake down the equipment and obtain early reservoir performance data to aid in planning the full watertiood. A single producing well was converted to water injection service as the f~icillties were commissioned. This well had been used in tht~ earlier injectivlty test program and had been producing for about 4 months since field start-up. With adequate pre-production and de-oxygenated seawater, this well performed on injection as expected. An additional 2 wells were added to the pilot and they also performed satisfactorily. Pressure fall off ,injection step rate and injection profiles were performed on the wells to determine fracture gradient, monitor fracture growth and determine injection profile. Radioactive tracers were also injected into the welts to monitor water breakthrough. The information gathered was used in planning the implementation of the fui! field watertiood. Early operation of the facilities also provided for Improvement in operations and pointed out the difficulties to be encountered during the summer open water season. Pressure declines experienced in the SDI area caused implsmentat~on of full waterflood into Zone 2 and Subzone 3A sands in the main producing area to be accelerated and completed by the end of 1988. The addition of peripheral areas and upper Zone 3 followed and is now complete. Well performance including infectivity and profile control has been acceptable with only minor remedial work required. large potential benefits of repressurization have greatly affected the operation of this waterflood project. Although the sea water injection facilities were nominally designed for 140 MBPD (22 300 m3/d) and have ir~ected over 160 MBPD (25 500 mild) on occasion, annual average rates have not yet exceeded 100 MBPD (15 900 m3/d). Thr Endicott Field fs located near the mouth of the Sagavanirktok River. High discharge rates during spring run off cause very high levels of suspended solids in the ocean near the sea water intake for the injection plant . High solids levels cause frequent injection restrictions rr shutdowns of the plant because of filter plugging. This problem can also be especially acute in the fall when seasonal storms churn the ocean. Many modifications have been made to the facilities which have resulted in same improvement. The addition of a clarifier was studied but the investment could not be justified. To compensate for the bw summer injection, lt has become necessary to overinject during the winter months to accommodate net voidage. The need to over inject during the winter caused several changes to be made to the facility design and operating strategy. 'fhe most important change involved a pilot injection test of commingled sea and produced waters. Commingling the two waters in the winter months allows a large increase in water injectian rates by using the produced water injection pump to inject the commingled water. There was a major concern about the formation of BaSO4-scale in the commingled water. The sea water has free ion concentrations of Barium while the produced water contains high concentrations of sulfate ions. To date, results from ttie commingling tests have shown little problem with scale formation. The reduced availability of injection water during the summer led to an unusual use for one well. Simulation of the 3A subzone estimated that a producer near the location of a 26 injector would recover an additional 0.6 MMSTBo (95 000 stock-tank m3). However, these calculated reserves would not justify the expense of drilling an additional well. Simulation of the 2B subzone showed that relatively small volumes of injection water were required for optimal 2B recovery. From these studies, the decision was made to altemateiy use the well as a 3A producer during the summer and a 2B injector during the winter. This well has a packer tailpipe and a sliding sleeve installed to allow isolation of each reservoir. The well has sufficient infectivity to meet annual injection needs during the winter months. FIELD PERFORMANCE TO DATE Although pilot injection began in early 1988, full development of the waterflood was not finished until mid 1990. There has been minimal well response to elate to sully evaluate watertiood performance. However, well response observed to date is consistent with model predictions. Radioactive tracer has been injected in 12 water and 3 gas injection wens. A systemaY~c well sampling program is in place to insure timely observation of breakthrough. Produced water from these watts is also analyzed for Ion content to differentiate sea water from reservoir water. Injection water breakthrough has been observed in 10 wells, confirmed by either radioactive tracer recovery a~id/or ton analysis. Most of the observed breakthrough is consistent with model predictions, with the few cases of early breakthrough explained by apparent high conductivity through mapped tauits. This type of surveillance work is critical, as aquifer water has broken through in several wails unrelated to watertiood. Most non- waterfiood breakthrough is the result of cement channels or aquifer movement along fault planes. Only about 25% of the 40 MBWPD (6400 m3/d) currently produced in the 107 6 gPE ~ ~ '~ ~ ~ GN AND IMPLEMENTATION OF THE FIR SPE 21760 ARCTIC OFFSHORE WATERFLOOD,ENDICOTT FIELD, ALASKA Endicott Field comes from waterfiood breakthrough. A few wetls have shown major decreased gas production in response to water injection. Figure 8 shows the GOR history of well K-16 and the dramatic decrease in well GOR in response to water injection. GOR response in most wells is more difficult to evaluate as these wells vary in offtake and are rate sensitive to gas production. Continued attentive monitoring of field performance is the key to increased recovery from the Endicott Field. Reservoir simulatbn w111 play a major role in this surveillance effort. A continued joint effort between reservoir modeling, production operations and geology groups is necessary to obtain maximum benefit for Endicott Field development. O,QNCLUSIONS 1. Early accurate and detailed reservoir description was essential in implementing the Endicott waterflood. 2. Early reservoir surveillance pressure information is directly responsible for modifying reservoir description and waterflood planning. 3. Amufti-disciplinary team approach is necessary to ensure successful waterflood planning and implementation. 4. Reservoir simulation will enhance the design process and lower costs in developing and producing new oi! fields. NOMENCLATURE TVDS~ =True vertical depth sub-sea OOIPg Original oil in place MBWDa Thousand barrels per day ACKNOWLFQGEMENT The authors wish to thank the management of t3P Exploration and the working interest owners of Endicott Field for permission to puotish this work. We also acknowledge present and previous co-workers for their significant contributions to the Endicott Project. We also thank Lynda Stamper for preparation of the manuscript. The work presented in this paper reflects the interpretations of BP Exploration and not necesarily those of the other working interest owners. 1. Wicks, .!. L., Buckingham, M. L., and Dupree, J. H., in press, "Endicott Field -Northern Alaska Offshore Beaufort Sea", American Association of Petroleum Geologists Atlas of Oil and Gas Fislds. 108 ~h ~~ ~_ - ~_~-, NE 17KILYARIAK FORMATION 3A SW NIAKUK FAIRT BLOCK mi ~ 38 i ~ z' ~ ~o sssuesEa ?A Y ~; , MITERM DIATE AOUIFE Y 3 D' ~ ~ ~ z C RELIC ~OWC ],OA~ ~ a28 ~~; 8 ~ ; ,;~ N ~ 2A rREGKNdAL AOUIFE ;G t~ ~~ I ~ ~x T _~~ ~ ~G ~ ~ ' ( DEVONIAN BASEMENT ;~ I • TAR APPROXIMATELY ONE-HALF MILE fi Figure 1- £ndicori Reid 4X ve:ticai exaggeration cross section. ~ Line of section shown on Figure 2. , 1LT GROSS OOIP POROSRY PERM. T-kCKNESS N : G { LS w I 258 (23%) .18 300 180-250 .33 .82 107 .18 150 90-170 21 .80 (9%) (17~) .~ 300 115-240 .53 .91 256 (2396) .~ 1000 30-180 .90 .90 (2696) 22 1200 190-230 .51 .94 (2~) .15 150 105.280 .19 .78 1,117 bIM " figure 3 -Endicott type section and average sutuona! properties. 1_._... ___ ._.~. f LCU • LOY+EA CRETACEOUS UNCONFORMITY TAUNCATION ~ SDI • SATELLITE OR1LLiNG ISLAND , A'!Pi -MAIN PRODUCTION !BLAND ~ ~ Figure 2 -Endicott Field fault map. Truncated structure at fop Kekiktuk. O •O N CL ~ • ~o ~~ c m t ~ r C « ~~ ON ~ ~ N 6L r- at ` N ~O C !n ~ . ~ r ~ ,O ~ a ~ ~ a a ~ ~ N; ~ c° t Ny ~ ~o ~ ~ ~ N QQ N ~~ ~ (~q W W O m 0 ati~ ~ ~ ~L n ~W ry ~ •~ W R i= ~ ~ /~ Y V ~' _` ) C. iD r U~~O O a 0 Qy/ ,' ~ ~ ti ' . ~ t ~ ~ '' ~~ N .' 1, ' ~ ° ~ Q R ~ k ~ ^ - 9 - ;~ O O ~ ~ a a O ~ ut9. ;~ ~` 11 ~ MI v ~ _ «~, ~~~ sP~ 2160 ~ -- _ ..N-39 '- SW • ~ 3C a r~ ;:i { ~,. M-39 J. K-39 J•39 NE ~ r ~~ PERFORATIONS I ' I 4X VERTICAL EXAGGERATION • Figure 6 -Unfolded SDI area cross section. Injection weH placement i by subzone. Line of section shown on Figure 4. ~St ;r•Q 'rq TA Wttls CP: Pw ffcm L~ SlGdf elof5 ~~~ {~li ef5 PN F.tiUStef 4pR Fr+r KOed tlr^i tt• ;ervacl 4vf u:l CU ; f~« , 5lawatr fiGm IrJlt L~ 1:: R ipwlr F n1M: I i 6cater i:r V:lII~ I .r~ lit;wPD , SW l:4r.St N! Figure 7 -Schematic for Endicott water injection facility. `.V! it7' m 0 N W N adMB • N0~1~3fN1 9t•l .- QO 3 ~j m v d d J 0 m w O Q a rn o a w o~ s g g s~ g~ s s ~^ 81SId~S • liOJ 91-~ 112 r J C G O w V d .-. C N eo r Y w 3 0 0 .. N by January 25, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mr. Steve Davies Alaska Oil and Gas Conservation Commission ~ ~} - 3001 Porcupine Drive ~ ' Anchorage, Alaska 99501 ~''~ ~~ ;~ ,~„ .~ ~ ,• 1 -,,~ Re: Proposed Endicott Well 2-28x/0-19 Spacing Variance Dear Steve: Enclosed please find a map and log cross section showing the proposed Endicott high angle TTRD sidetrack well 2-28x/0-19. 2-28a/0-19 is intended to drain Subzone K2B oil downdip of the gas prone K2B at 2-14/0-16, and updip of the water swept K2B at 2-28/P-19. Well 2-14/0-16, the nearest existing well to the proposed 2-28a/0-19 BHL, is approximately 200 feet horizontal distance from the TD location of the proposed K2B 2-28a/0-19 producer. 2-14/0-16 however produces from the K2A, a deeper subzone at Endicott. Endicott Subzones K2A and K2B are separated vertically by a field-wide stratigraphic hydraulic barrier, the K2M shale, ranging from 20-40 feet TVD in the area. Recent static pressures (-10000 ft TVDss datum) indicate a reservoir pressure of 4585 psia for the K2B (2-28/P-19), and 4306 psia for the K2A (1-33b/-24), a differential of 279 psia. Well 2-14/0-16 is a former K2B producer, however the zone was completely squeezed off in December 1998 due to high gas production and mechanical problems (combination of failed squeeze perforations behind a straddle and corroded straddle tubing). Consequently there are no plans at this time to attempt to access K2B at 2-14/0-16 due to the risk of jeopardizing the existing K2A production in the well. Current K2B producing wells near the planned 2-28a/0-19 BHL include 1-03/P- 16and 2-28/P-19. These wells are located (midpoint of producing intervals) at a horizontal distance of approximately 1500 feet to the north, and 1175 feet to the southwest, respectively, of the planned 2-28a/P-19 K2B well. • rr BPX (Alaska) Inc. requests administrative approval to waive requirements stipulated in Title 20, AAC 25.055 (3) and allow well 2-28x/0-19 to be permitted within 1000 feet of existing well 2-14/0-16. Please contact me at 564-5345 if you wish to discuss this matter in further detail. Sincerely, ~~~ y , \~ rent J. Voorhees bjv encl: Well location map Offset well log cross section cc: 2-28x/0-19 well file ec: Weggeland, M. Vandergon, M. Robertson, D. Hupp, J. Ding, E. Voorhees, B. ,~ x" r-~-1 ~-1 ~lQ . ~..~ r by 0-19 K28L MPI Target cn ca ao m cn co m m ~, cn W m 256500 .j ~ ~ { ~ p ~ tS~ 5 5 .` ~~ Driller's a et ~ ~'~- ~ ., ti, y Harcln ~~ i ~ ti1 ~ '' \ - {~ ~ ~ ~~. ~.- 444444 - r ~~ , ~ t ~~ ~, f 1-1 ~~ ~ , 2- 9 8' ~ ,t ` ~ ~, Volumetric ,, ~, ~ s~ ~, '`~ -- -- 9 r ~ v~ - ~~ 1 ,~ ~, Polygon . ~'~, ~ ~ .~~~o- ~~~'' ~~ ''`~,,~_ ~ .~ ~ ~ E,, 1 9b~~ ..'F., ,~ . ~~841 ~ ~ ~ s ~ ~.~ 1 1t SSS~~, ~ ~ ~4 ~ - ~ ao ~. $~ _ ~ ~ ~,, Cfl (D W N m ~, m m U7 to m 2-28a/0-19 TTRD Drilling Proposal ~ ~~~~ Target Location Map 2001 Endicott Field Drilling Program 257500 258500 259500 260500 261500 262500 ~ 259 BD ~ r + ~CI} ~ •- 1 -25;'N-22 ~ ~ ~ ~ r' _ 2 P ~ 1 y s9a~a~e-- ,r ,~ ~' r~~ cS` ~ -1 ~ "81 `;-_, ,• / ~ ~t X4$15 ~`~ ~ ~~ ,, ti,, ~~ `' ~`` -9819 ,~ SO/~ OF IVdIICfC~L Eli t~ . ~; ~~ bG~ ~~ a 4`, ~. _ _ ~ ~~, 9 `~-~-. 0-19 TTRD Drilling T r et Location Map - - _~~ '~ ~~--._ ~ ~``'~~ Blue Contours Top 2500f TVBss, K2A/K2M Faults, Color Contours Current GLAC Thickness ~'~. ao 6500 257500 258500 259500 260500 261500 262500 cn ca ca cn m cn 00 m m ~, rn W m m • CJl CO ~ D fV C6 ~ m ~ s~ D ~ _ ~, ~N 00 ~"' ~i6 Ul ~n ~ O ~ `° Op o N C _ ~ O O pp r r7 Ct~ a~ m a, m Attachment 2 "~~~ ~ - - .__ 2-28a 0-19 TTRD Drilling Proposal ~~ ~j~`-~~'~~ ' Offset Wells Log Cross Section N-24 K2A MPl Target 2001 Endicott Field Drilling Program 'L"P-',~,RtlNItlNflIIFdiIllGfilp'~~AW'~~"~~ w«u+~ ., h~1,rxIVryAI ~.Y a~A1L:!Si..~Lr..S4~44'.'~ihP7°Pv711V.vPae.P.~IYiWPav~'1^,Y~IMEYl4s~RIP15kVNN!'yi'[%d!'~.&~.~L^i~4l:d?BF!!.'k.Y~pX.VNfd"%WGft1W!'~Y9~'!M'~@YN'1P0.Td~ "Mdc~pT~VY"aYMb^~li%1414ig64LVk5iY.FNS4c$~v,ikRlC uu.NJ 4~...~b~1''tlld~n,~..#z,:r.... Y ~ .^...:Y...°Jk P"I~~ d. 2-14/0-16 south 2-28/P-19 ~.,, ~~~„~ w~~ „~ North ~ - 1750 ft - - ~ ~. „ass 1~ .rw~ K3A ~~ vertical scale K2B (upper} Mid K2B (lowe~r~ K2M Shale K2A K26 lower has long transisiton zone with OWC at, or near top of sand 100 ft 0 K2B cemented off prior to depletion due to mechanical problems (3 mmbo cum); RST OWC p50 -10061 `ss Attachment 6 JAN 26 '01 10~38AM BP MIL POINT GROUP BP EXPLORATION Fax cover Shcot To: CMS , 5~~. ~_ ,~,~~~ C~ ~~~~~-~~ T Phone:-- ~w ~' ` Zi'2r~ ---- 1-- Fax phone: Z.`~ ~ ~ ~ S `~?r CC: P.1 Dace: ~p. „y1 ~ Number of pages including cover sheet: ~.~ From: ~ /' /""~_~ REMARKS:( r a ^ For your review ^ Reply ASAP ^ Flease coaunenE ~S G~~~Jb~e~k -~c~,~ ~c.~ ~~' t,~.~,~ ~ '~-~30, ~Q~ ~-~~q r~ ~ ~a,~ ~- ~~,.-- ~~ce~.t~~s -~~.~ CEIV~p ~~t~! 2 6 2041 Alamo Lkl ~ lion FSx phone: ~, ~ - ~ ~~e ~4? JAN 26 '81 10~39AM BP MILNE POINT GROUP by ~ ~ BP Exploration IAlaskal Ina 800 East Benson Boulevard P. p. Box 196812 Anc4~oraga, Alaska 996198612 (90n 561.5111 January 25, 2001 Mr, Steve Davies Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Proposed Endicott Well 2-88a/0-19 Spacine Variance Dear Steve: P.2 Enclosed please find a map and log cross section showing the proposed Endicott high angle TTRD sidetrack we112-28a/0-19. 2-28a/d-19 is intended to drain Subzone K26 oil downdip of the gas prone K26 at 2.14/0-16, and updip of the water swept K2B at 2-28/P-19. Well 2.14/0-16, the nearest existing well to the proposed 2-28x10.19 BHL, is approximately 200 feet horizontal distance from the TD location of the proposed K2B 2-28a/0-19 producer. 2-14/0-16 however produces from the K2A, a deeper subzone at Endicott. Endicott Subzones K2A and K2B are separated vertically by a field-wide stratigraphic hydraulic barrier, the K2M shale, ranging from a0-40 feet TVD in the area. Recent static pressures (-10000 ft TVDss datum) indicate a reservoir pressure of 4585 psis for the K2B (2-28/P-19}, and 4306 psis for the K2A (1-33b/-24), a differential of 279 psis, Well 2-14/0-16 is a former K2B producer, however the zone was completely squeezed off in December 1998 due to high gas production and mechanical problems (combination of failed squeeze perforations behind a straddle and corroded straddle tubing). Consequently there are no plans at this time to attempt to access K2B at 2-14/0.16 due to the risk of jeopardizing the existing K2A production in the well. Gurrent K2B .producing wells near the planned 2-28a/0-19 BHL include 1-03/P- 16and 2-28IP-19. These wells are located (midpoint of producing intervals) at a horizontal distance of approximately 1500 feet to the north, and 1175 feet to the southwest, respectively, of the planned 2-28a/P-19 K2B well, JAN 26 '81 10~39AM BP M~E POINT CROUP ~ P.3 BF'X (Alaska) tnc, requests administrative approval to waive requirements stipulated in Title 20, AAC 25,055 (3) and allow well 2.2$x/0-19 to be permitted within 1000 feet of existing well 2-1 ~4lO-16. Please contact me at 564-5345 if you wish to discuss this matter in further detail. Sincerely, rent J. Voorhees bjv encl: Wall location map Offset well log cross section cc: 2-2$a/0-19 well fiile ec: Weggeland, M. Vandergon, M. Robertson, D. Hupp, J. Ding, E. Voorhees, B. _._~_, ` `;_ ~ _ ~ - . ~ 2-28a1~-'19 TTR© Drilling Proposal ~ ~ "` ~--. _ _ - ~- Target Location Map D 0-~9 r'f2BL ARP Targef 1009 F»clYcoft Ffelr! Drt7lirty Pmggrartt z- m 25650® 257500 Z585Qi9 253500 2SH5HF~ 261500 262500 '~ rn m a to ffi _~ .~ m m S~ m N lb m m m m -m m m .. . _: -- -_ - _ - .-. _ ~ 9 .. _ - _ _ ~_= l ~-_-~-- ~ . _ __ __ _ _ _ ~' _3 ~ ~ s-l _ _ _ _~' ~. _ - __ __ ` _- ~_ ~~ a ~_- - ,:; Wiper's - - __ -- - _ _'~ (lard °~.,~~, •' ;~ = _~ \ ~ ' ~ ~ - ~ - c'~ .~- 1 -__ --_ -- _ ~..~r -_ _ ~ 1Fs f~ 1 _ _ ss~ v~ _ _. E~ `~1 -19 TTEtD ©rilling T_ r et Location BLL~C~f1~flUr'3 ~IID 21~~5 ~3'S~ ~~~{'~ ~al1~~Sr_~IOI' ~Oi1~UUP3 ~ 850@ 257500 258509 Z~S56O Z6O5O~f 2SL5O0 262500 ~F" ,$~~ ~ ~ ~ ~~ ~_ ~ - _ ' -_ 111 S '' 1-253N-22 <~_°-_.: -- x$15 ~,~ --=___ ~- a -: _ .y ~~.. -__ `~ ra F-- aQ m ~ A w m ~ D m 3 -~ ~3 H cn r m Z ~- o 0 ~ ~ ~r Cil N m A (A AD 0 W m Attachment 2 JAN 26 '81 10~40AM BP MILNE POINT GROUP P.5 I ~E~~4~i ~ ~ ~~~ ~,_ ~~:~`°~~~'~'~`~~ 2-28a/0-19 TTRD Drilling Proposal ~ ,i~ ~'~~ ~ ,. - ,~ ;- ~'~~~~ Offset Wells Log Cross Section N-24 ~K2A MPl Target 2001 Endicott Field Drilling Pmgram f:'::,.,„,,,;.:a;tre;:.$:~r ~~~a:s7~.:,dao~~csa7,A®'ffiGll~ 2-14/0-1 s south ~-28/P-19 ~e~ . fdorth •~- - 1750 ft - - +- '.a ~'--~ "~ ~-ss wa~.,.~ K3A vertical scale K2B (upper) Mid KZB~ (lowdwr~ , 1 l KZM Shale K2A~ K2B lower has long transisiton zone with OWC at, or near top of sand 100 ft 0 KZB cemented off prior to depletion due to mechanical problems (3 mmbo cum); RST OWC p50 ~10061`ss Attachment 6 ~~~ • • ALASKA OII, AND GAS CONSERVATION COMMISSION BPX - DIU Meeting August 6,1998 9:00 AM SIGN IN PLEASE NAME -COMPANY r~,2y ~~/rlsy.~ 13~x ~~~-K ~i Ka~S ~~~' lf?~~i ~~+~A-~-~ Aoyu- ~k~- ~~~ /~7 C G ~~~~ ~ o ~ LJ~~cs • W W W N Yl IA NOO r aaa rrr rrn `.~ • G~f ~, 4 ~~ ~~ ~ J~~--P~, ~ E~~`°` ~W d_,~ ®~ ~, _ ~,v' y 21 ~ 3 ~~ ~c t ~ ~~ ~R- • • `~ 8 3 ~ L ~` -~ S2 ~ ~'' ~f _,,i-~"~'° ~ ~y.s ~ ,~f~.~/ sue' . ~ `n/ ~J N N ,~=.~r~~~ry N (/'~ .~ r N~ ,ice ~~ .. N N N _ _ _ N T m T T T ~ 1 ~ N N N At • l~~f ~'~ ~j~f 1~ a • N VI Yf W W W NtI1N 000 h O O ~C aaa C N N r~~ w( • t3 .~:.~.~.-'g 17 d ~0 2~2 ,~- 22.3 g ~~ ~ ~~P ~~ ~ ~~ ~ c P ~ ~^^-,-~. , Pry ~~~' ~ ~~ 1, 5 ~ ~~ P P.L~ ~~1~ ~, o ~ sra o _9~ ~~~ ~'~s c~ P2L f r~ D.~ S~~ t ~C p v~ ~ ~'~ Gum ~`~.-~ ~ L~~f ~~ ~, ~. +- C- ~ ~~ ~ ~~~~ ~ 5~ P ~, / ~~ ~ ~~, ~~~ ~ m ~-~ i' r ., "\.~p ~" + 8/8/yg AOGCCC0202 r AltaGtCCi GQ 2Q~ R~tY[StOC1 R~qt~@Sf • Agenda - co 202 - Endicott Context - Badami Development - Badami Gas Requirement - Endicott Impact - Recommendation 8/6/98 AOGCC CO 202 Endiccatt ~t~nser~r~~i~t~ f,~~pders • CO 202:1984 - Endicott development & offtake rates • CO 297:1992 - 20 AAC 25.280(a) exemption (drilling approvals) • CO 334:1994 - CO 202 amendment :surface casing depths • CO 399:1997 - CO 202 amendment :pressure survey requirement z 1 u A ~, -. ~ ~ 8/6/98 AOGCC CO 202 ~~ ~ °~~,r ° ` ~Q 2Q2 Ral~ 1~ (d~ i..~..~... ..... _ "Gas offtake is not permitted because the reservoir depletion program governed by this order requires that produced gas be injected into the Endicott Oil Pool. At anytime, upon proper petition and after public hearing, the Commission will consider the merits of issuing an order establishing a gas offtake rate. That order would provide for appropriate amendments to the pool depletion program governed by this order to ensure that a loss in ultimate recovery will not occur." 3 8/6/98 AOGCC CO 202 Endicott context - _:~ ~_. a ®.._. . _ 4 2 Production started 1987, peaked at 1 t 5 MBD in 1992 and is currently averaging about 60 M9D. • t ~~ ~ 8/6/98 AOGCC CO 202 ~c'!~c'I1111 PCO~@Gt 1J n J ~,.~Endfoott N"~`'~M-, Sadami Facts rr Facility Est. Reserves 120 mmb gross Plateau Production 35 mbd gross Est. Cost $300 million BPX:Operator 70% Fina 30°k ,.1 KvP ~lp~/ ej ~ ~ ~ SS_ s~~ .~` _ Cr4~e ~+po ,l'~trne (NGL & Gas 1 Ba dial yl ~I,;, ft to pc ' - p / ~~ y ~~J 5 •. 8/6/98 AOGCC CO 202 _. . ~` - ' Estimated Eras ~aet~a-rt Rats ~. - Sadami requires gas for field commissioning (9/98) and FOR (1/99) - Requirement is dependent on Sadami gas production and FOR performance - Estimated Rate : up to 25 mmscf/d, Volume :100 BCF over 20 years - Anticipated Export Profile 28 s E 20 _ E q 15 W o i0 Y E 8 x W 0 lara ~u00 2002 2004 2008 2008 2010 2012 2010 2018 2018 2020 3 • • ,; `~`` 8/698 AOGCC CO 202 E~.4.~ ~,~~ Endicott Impact • Transfer estimated 100 BCF gas (14 mmboe) from Endicott to Badami • Voidage at Endicott can be offset by increased water injection • Reduced gas cycling impacts Endicott's vapor- borne liquids recovery by 0.7 mmbo 86/98 AOGCC CO 202 ,Endicott : vapor-borne Liquids [.h:AN G.4S ORIGAiAL GOC ~ckd) 8 4 r ~ • • ~: a~ ~ 8/6/98 AOGCC CO 202 :r; ' ~~~~ _ = Endicott : ilapor-borne Liquids >. ~a o d~ s ~~ ~~ ~ ~~ w a Endicott GHX Proj Main Gas Compressor Turbine Upgrade Approved December 1997 Gas ProductioMnjection to Increase by 49 mmscf/d annual average Additional Vaporization Recovery . 2.7 mmstb a a~ E 12 mm4YM ~b m; _ yc t'n 50 mmscVd ~"~arCYpID' ~"`~afino°"°' Gas export to Badami reduces Endicott gas ouvaPO,t~eda,arti,~cuo„wGascyda~at~,~~y,~ injection by 12 mmscf/d annual average a o,ioo ~ am zsa~ for ~, a~ and as4aai a~ Recovery curve is approx. straight line Endicott VBL impact = 0.7 mmstb 9 8/6/98 AOGCC CO 202 Recommendation • Amend CO 202 to permit gas offtake - Recommended language - "Pursuant to rule 13 (d) of CO 202, the Commission hereby establishes a gas offtake rate of up to 25 mmscf/d from the Endicott Oil Pool" to 5 Bureau of Mires Study, 1969 6. OC OC OC G v a Wells on Oil Production W .P O Ui O Ui O Q IX IX OC (w .~ v 6 t W ? CJl O O O O O O O O O O O O N O O O O O O O O m z 0 n 0 m z 0 n O O r O O r ENDICOTT - ENDICOTT OIL POOL 375000 ~° 300000 U 0 225000 U_ m ~ 150000 c 75000 0 86 87 88 89 90 91 92 93 94 95 96 97 98 1000000 800000 600000 ~ 400000 .~ 200000 0 86 87 88 89 90 91 92 93 94 95 96 97 98 25 - - ~ Wells on Gas Injection - - Wells on Water Injection 20 15 10 5 .. .. .. ..~^,.:L .'~M,/u~[\ ln~ . ... .. .. .. .... .. .. .. .. .. .. La!yn ~_._ .rv..~:r,!.',GV~LV..ar _ .. ~, u~~. ... ................ ............___ _..__...._ _ ._..._ ......._.. .......... C. ... _ ~~ T, A .'.1f.P1.Y_~ 0 86 87 88 89 90 91 92 93 94 95 96 97 98 Wells on Oil Production W A ~ 1 1 1 ~ 1 1 Q ~ Q QJ ON QW ~p Q 0 I i i i i i i I i i 0 0 0 a a C u u c v v n u c C V C U O rn 'C i , p 6 p C ~ ~N g ~~~ _ ~- -__ y _ ao m ~ .... ..~ ~: ~ ~ _ a~ ~ - ~n~ ; F o~ V ` ` n s o~~ '-' ~;? ~ ~ ^~~, ~ o c o Q .~ ~~/ ~ ` _ ~\ '~ ' ) o ~ _, _. _. ~ ' ~ ~ cD ~ t > ^' !, l l > cfl N ~' ', \ ~ ~ _ K ~ ~/ w 1 p p ~ , _ ~ t 1 ~ ~ y ~ ~ ~ \ ~ ' ~ J ~ 61 ~ ~ _~ -- ' ~ ~:_ ~z ~ ` ~ v ' , _.... ,_. x y ' . ! { ~ ~ ,. ~ ', m z 0 n -~ m Z O ---~ "'~ O r 45 OR161i~:4L • (Corrected) Notice of Public Hearing • STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Endicott Oil Pool -Duck Island Unit BP Exploration (Alaska) Inc. by letter dated June 26, 1998 petitioned the Commission for an amendment to Conservation Order No. 202 to enable gas offtake from the Endicott Oil Pool for delivery to the Badami oil field for purposes of fuel use and enhanced oil recovery operations. Rule 13d of CO No. 202 states in part, "Gas offtake is not permitted because the reservoir depletion plan governed by this order requires that produced gas be injected into the Endicott Oil Pool. At anytime, upon proper petition and after public hearing, the Commission will consider the merits of issuing an order establishing a gas offtake rate." A person who may be harmed if the requested order is issued may file a written protest prior to 4:OOPM, July 27, 1998 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 AM on August 20, 1998, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after July 27, 1998. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than August 10, 1998. Published July 11, 1998 ADN AO 02914002 ~~15780 STOF0330 AO-02914002 $78.39 AFFIDAVIT OF PUBLICATION STATE OF ALASKA, THIRD JUDICIAL DISTRICT. Eva Z•7. Kaufmann ................................................... being first duly sworn on oath deposes and says that he/she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental farm) of said newspaper on July 11, 1998 and that such newspaper was regularly distributed to its subscribers during alt of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. ~~ '~11 Subscribed and sworn t fore me this ..~ ~ . day ofs\.,. 19~~ t l f (( C~ ~ G , G'~ Notary ~b® ip~nA ~r' ..~ ~ the S of Alaska. v~ . Ir ^^~ .. rag,~„Qlask ~ 'Ab SION • •~`"~ ............. JJJ'~~i,~~ . ~F' i-'D~°°'- ~ 11,9..... . X1))17 (Corrected). issued may file a written pro- Notice of Publie }learing test prior to 4:OOPM, July 27, STATE OF ALI(5KA 1998 with the Alaska Oil and Oil and Gos Conservation Gas Conservation Commission, Commi~sioa; .: 3001 Porcupine Drive, Anchor- Re: Enditoft Oil Pool • Duck' a9e' Alaska 99501, and request Island Unit a hearing on the matter. If the BP Exploration. lAlcssko) rp ses to isubstantial anddmate- I nc. by later dated Lane 26, rial issue crucial to the 1996 petitioned the Commission Commission's determinpfion, a for an amendment To Conner- hearing on the matter will be, vation Order No. 202 fo enable held at the above address ai' gas offtake from the Endicott 9; Dp qM on August 20, 7998, in Oil Pool for delivery to the conformance with -20 AAC ~Badami oil field for purposes 25.540. If a hearing is to be of fuel'use and enhanced oil held, interested ,parties may recovery operations. Rule 13d confirm this by calling the of CO No. 202 states in part, Commission's office, (907) "Gas offtake is not permitted 279.1433, after July 27, 1998. If because The reservoir deple- no protest is filed, itre Com- tion plan 9overnetl by this mission will consider the issu- order requires that produced anceof the order without a gas be inieded into the hearing. Endiwt} Oil Pool. At anytime, If you area person with b upon grocer petition and after tl(sability who may need a public hearing, the Commis- special modification in order ;ion will consider the merits of to comment or to pTTEnd the '~ssuin9 an order establishing a public hearing, please-contact aas offtake rate.° Diana Fleck of 279-iz33 no A person who may beharm- later than August 70, 199, !d if the requested order is /yDavid W. Johnston Chairman AO D2914002 - f gib.: July 11, 1998 44 ~J Notice of Public Hearing • STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Endicott Oil Pool -Duck Island Unit BP Exploration (Alaska) Inc. by letter dated June 26, 1998 petitioned the Commission for an amendment to Conservation Order No. 202 to enable gas offtake from the Endicott Oil Pool for delivery to the Badami oil field for purposes of fuel use and enhanced oil recovery operations. Rule 13d of CO No. 202 states in part, "Gas offtake is not permitted because the reservoir depletion plan governed by this order requires that produced gas be injected into the Endicott Oil Pool. At anytime, upon proper petition and after public hearing, the Commission will consider the merits of issuing an order establishing a gas offtake rate." A person who may be harmed if the requested order is issued may file a written protest prior to 4:OOPM, July 23, 1998 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 AM on August 20, 1998, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after July 23, 1998. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than July 29, 1998. Published July 10, 1998 ADN AO 02914001 ik9132 STOF0330 AO-02914001 $77.22 AFFIDAVIT OF PLIBLICATI4N STATE OF ALAS[CA, THIRD JUDICIAL DISTRICT, Eva T•1. Kaufmann being first duly sworn on oath deposes and says that he/she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on u ~ r and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. g~~ Subscribed and sworn to Eore me thips~..~ ~ day of .. ...... . 19..7. a ~ t; ..A.. ~~~.~. ~o~ I' i "' d f~~ ~ =- ~ihd ~9f~on~. ••. ~- ~1nch PP a f~t0 ®_FiIRE$ °°~~ • ~~ • J~E '1Jo"- 1' JJli.t~illl~~ Notice o9 Public Hearing `. STATE OF ALASKA OII and Gos Conservation Commission Re: Endicott Oil Pool -Duck Islond Unit BP Exploration (Alaska) Inc. by later dated June 36, 7996 petitioned the Commission .for an amendment to Conser- option Order No. 202 to enable `gcs dfttake from the Endicott Oil Pool for, delivery td fhe Badami oil field for purposes of fuel use and enhanced oil F@aaverY operations. Rule 13d GasOofftoke02s snote5permptir¢d because the reservoir deple• ifon plan governed by this order requires that produced . gas be infected into the Endicott Oil Pooi. At anvttrne, .Upon groper petition and after public hearing, the Commis- sion will consider the merits of issuing do order establishing o '9a5 offioke rate." A p:r;on who may Ue harm- ed if the requested order is i55Ued may file a written pro- tssf prior to 4:OOPM, July 23, 1998 with the Alaska Oil and Gas Conservation Commission, 3007 Porcupine Drive, Anchor- age, Alaska 99501, and request a bearing on the matter If the protest is timelY~ filed a0i1: raises a substantiot'.and mate-, rla6issue crucial to the... Commission's determination, o hearing on the matter will be held at the above address aT 9:00 AM on August 20, 7998, in Conformancewith ?D AAC 25.540. if a hearing is to be held, interested parties may confirm. this by - tolling The :.Commission's office, .(907) 219.1433, after July 23, 7998. If ino protest is filed, The Com- mission wiH consider the Jssu- once' of the order without a hearing.. ' If you are d person 'with a disability' wiw may need a Special modification in order to comment or To attend the public hearing, please contact Diana Fleck at 279-1433 no later than July 29, 1998. /ypavlcf W. Johnston Chairman . Q 02914001 43 ~ i ~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 State of Alaska June 26, 1998 Alaska Oil & Gas Conservation Commission Hand Delivered 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: Mr. David W. Johnston, Chairman Re: Endicott Oil Pool -- Petition for Amendment Dear Mr. Johnston: BP Exploration (Alaska) Inc., as operator of the Duck Island Unit, hereby requests the Commission to amend Conservation Order No. 202 to enable gas offtake from the Endicott Oil Pool for delivery of gas into the Badami Gas and Products Pipeline. The Endicott Working Interest Owners have been notified by the Badami Unit Working Interest Owners of their desire to import gas from the Endicott Oil Pool for use as initial fuel gas to enable Badami start-up operations, and in the longer term, for injection into the Badami Oil Pool for enhanced oil recovery operations. The gas would. be transported via the Badami Gas and Products Pipeline (Right-of-Way Lease ADL 415965). Currently, Conservation Order No. 202 states, "Gas offtake is not permitted because the reservoir depletion plan governed by this order requires that produced gas be injected into the Endicott Oil Pool. At anytime, upon proper petition and after public hearing, the Commission will consider the merits of issuing an order establishing a gas offtake rate. That order would provide for appropriate amendments to the pool depletion program governed by this order to ensure that a loss in ultimate recovery will not occur." The gas offtake rate requested by the Badami Unit Working Interest Owners is limited to 25 MM scf/d. The Badami Unit Working Interest Owners have advised the Endicott Working Interest Owners of their wish to begin fuel gas import for start-up and commissioning purposes in early August, 1998. Import of gas for FOR operations at Badami is sought by January, 1999. BPXA believes this request provides an opportunity to convert Endicott gas resources into marketable reserves, as well as providing a means to enable enhanced oil recovery from the Badami Oil Pool. BPXA is prepared to meet with the Commission to present any additional justification required for this request. • • Thank you for your attention in this matter. Any questions or comments you may have can be directed to Dave Szabo, Endicott Subsurface Manager, at (907) 564-4788. Si Simb, P ter BPXA~ ro uction Manager, Eastern North Slope cc: Endicott Working Interest Owners Badami Working Interest Owners X42 M BP EXPLORATION May 3, 1996 Dave Johnston, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 M BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage (907) 561: n-~~L C.. `.i / ~~ 1 Q~ M~'" Commissi~ /~ ~~ ~ ~6 ~; o t,,,.. o/~~ ~~ f P l'Ny ~ bl!/ RE: Year End 1995 Endicott Oil Pool - Reservoir S eillance Reps Dear Mr. Johnston: Attached is the 1995 annual Endicott Reservoir Surveillance Report. This report is a compilation of three previous reports tracking the Key Well Pressure Program, Key. Well Gas-Oil Contact Monitoring Program, and the Waterflood Surveillance Program. To the extent possible, most of the report and exhibit formats are still the same. Hopefully, compiling these reports will make it easier for all parties involved to monitor reservoir performance. We will endeavor to report on each year of reservoir performance by the end of the first quarter of the following year. Also attached attached is the Endicott Semi-Annual Casing Pressure Report. As in the past, BP Exploration extends an offer to brief the AOGCC regarding the reservoir depletion status and future plans for the pool. Please advise Steve Deckert at 564-4128 concerning a convenient time for a meeting or if there are any other questions. Sincerely, Q~~ Dave Sza Manager, Endicott Subsurface SLD `,~~~~ Alaska ail 8~ G..; ;cn Cammtsslon Ar~chc~rwge cc: Reservoir Development Group Members File 06.10 Attachments: 1995 Endicott Reservoir Surveillance Report Endicott Semi-Annual Casing Pressure Report ENDICOTT SEMI-ANNUAL CASING PRESSURE REPORT 1 s PREPARED BY: D. Van Tuyl / S. Merrett DATE: Mar-96 APPROVED BY: R. Allan / D. WIIIIams DATE: Mar-96 Jul-95 Aug-95 Sep-95 Oct-95 Nov-95 Dec-95 WELL TYPE IAP OAP IAP OAP IAP OAP IAP OAP IAP OAP IAP OAP [i ,6] [21 [3] [2] [~l [Sl [2] [2l [2] [3] [2.41 [2] [2s] [5] [2] [21 [2) {2] [2l [21 [2] [2] [~] [2] [3] 12] [2] [1] Thermal expansion due to increased gas rate and temperature [2] Thermal expansion due to increased injection water temperature resuRing from higher PW/SW ratio. [3] Tubing leak. Sundry filed with AOGCC [4] Tubing leak. Sundry filed with AOGCC. RWO completed 9/2/95. [5) Very slow thread leak suspected. Passed last MIT. Investigation ongoing. [6] Fluid pack inner annulus for rig move to adjacent well; subsequent thermal expansion [7] Pressure buildup is intermittent; potential RP valve leaking; continuing to monitor. [8] Converted from production to injection service in 12/95. [9] Investigation of tubing to inner annulus communication is in progress. 1-05/0-20 GI 1000 200 1000 250 1000 200 1920 200 850 200 850 200 1-11/SN-04 WI 1400 150 125 150 200 100 380 150 100 1000 80 100 1-15/P-25 GI 1800 100 1600 150 1600 150 1600 100 1730 160 1800 200 1-23/0-15 WI 360 940 350 100 500 1200 400 0 310 400 300 0 1-37/P-24 W1 380 350 200 260 700 250 1800 300 450 250 160 320 1-41/0-23 WUP 2700 40 1-43/P-26 WI 100 90 100 100 800 200 1100 260 700 100 50 150 1-51N-20 WI 450 50 460 50 450 100 600 60 450 150 410 200 1-69N-19 WI 0 720 0 325 600 700 1200 800 0 200 0 220 2-02/P-18 CDW 220 250 200 240 175 240 150 300 120 160 110 100 2-06/J-22 GI 2750 200 2200 200 1800 250 2300 250 2350 200 2510 200 2-12lQ-16 GI 340 50 350 100 400 40 400 90 400 50 700 100 2-16/M-16 WI 1700 150 1200 150 2700 200 700 20 1730 0 1700 400 2-22/L-14 WI 0 160 0 160 200 200 510 200 0 200 0 200 2-24/M-24 WI 2720 200 360 50 700 200 1100 540 580 130 460 40 2~OJ0-09 WI 100 150 150 160 220 160 300 200 500 170 1150 200 2-34/P-14 - WI 1700 50 1850 0 1750 200 1700 400 1600 0 1600 0 2-44/R-12 WI 150 200 150 160 400 200 600 200 1490 200 160 200 2-54/Q-12 WI 325 500 200 100 360 660 400 900 280 200 200 100 2-64/U-10 WI 440 100 500 500 500 460 500 100 320 310 320 100 2-70/U-15 WI 520 800 260 250 360 1300 700 1100 200 1150 100 260 3-07M-28 WI 700 690 0 0 250 1650 700 1450 300 700 0 0 3-41/K-39 WI 40 550 50 250 150 950 800 700 1150 700 100 1180 3-45/M-39 WI 540 620 0 0 50 100 820 780 100 280 100 0 3-47/G~5 WI 2150 1050 500 50 900 1000 1800 1500 510 490 200 50 4-02/Q-28 WI 500 1250 400 400 500 1200 400 1150 340 100 300 70 4-04IT-26 WI 200 220 150 150 150 120 120 320 50 125 120 120 4-08/P-27 WI 2950 50 1700 100 2500 60 2400 100 3000 50 760 100 4-14/R-34 WI 260 20 100 100 100 0 150 20 50 0 80 0 4-40/P-43 WI 800 1200 440 125 450 870 1050 1200 400 20 400 20 4-44/M-44 WI 0 0 50 100 100 100 100 200 120 140 80 160 4-48/K-43 WI 200 75 180 150 200 100 200 200 920 200 300 220 5-01/SAG 7 GI 1100 0 1100 50 1100 100 1000 200 1000 100 1250 0 5-02/SAG 10 WI 1860 200 600 100 2400 360 1500 600 1900 200 1560 1400 5-03lSAG 9 WI 900 100 925 100 1100 900 1600 100 500 100 150 100 w C W rn ~ a, v ..~ ~ o " W _ " V >.- ~ ~~ Q dS ~ ~ Y N «t a X41 • BP EXPLORATION December 18, 1995 Mr. Robert R. Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Proposed Endicott Well 1-59/0-24 Spacing Variance Dear Bob: Enclosed please find a map and type log showing the proposed Subzone 2B Endicott horizontal well 1-59/0-24. The well targets Subzone 2B reserves considered outside a drainage area accessible from adjacent 2B production in well 1-35/0-25. The horizontal distance between the planned end of the horizontal section in 1-59/0-24 to existing production well 1-35/0- 25 is = 1120'. This lateral separation is within guidelines established in Title 20, AAC 25.055 (3). The horizontal distance between planned well 1-59/0-24 and existing well 5-02/SD-10, at the 2B target horizon, is ~ 175'. A type log of well 5-02/SD- 10 is enclosed. Although well 5-02 could conceivably be considered "capable" of producing Subzone 2B reserves targeted in well 1-59, well 5-02/SD-10 will remain in service as a Subzone 2A water injection well. Recent statics indicate approximately 230 psi pressure difference between the 2A and 2B subzones in this portion of the Endicott Pool. BPX (Alaska) Inc. requests administrative approval to waive requirements stipulated in Title 20, AAC 25.055 (3) and allow well 1-59/0-24 to be permitted within 1000' of existing well 5-02/SD-10. The wells are to be completed within hydraulically separate reservoir subzones and no reservoir development plans exist to change the service of well 5-02/SD-10 from subzone 2A injection. Please contact me at 564-4613 if you wish to discuss this matter in further detail. An application for Permit to Drill will follow under a seperate cover letter. Sincerely, • /~ ~~ Robert etzger • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ~~~ 2 2 1°95 9aE.~~:u. psi ~~ (~~v ~t?~ . tai~~iilZS~igr ;~~,r~~~ar~~~ MPI WELL 2/SD-10 RT. F1.E17.WS TREE NnS~S000 pY/LkFrvy~AJwan aF.19EV.la.r wlaulEAV us~r7s]ooP.I,.kE,v,. YA7L DEV. • tOAt 7eoo to ® SSSV LANDING NIPPLE 1605 I3J10, ~~ 400 ~ ~ OTIS (].e13' ID.) • W55SV 0/ M01 L0.20' Leos ~~• 412• u6u0. L 00 ros , , - OUlI (1S PxAN) II ~IIS 127T f2 6~' 7{95• I] 7775• 0575• I~ 0716' 10650' IS 0625 10002 M 1 ~• n.. r6..xq wPw. t.w.~. r a~ Aq: I I SL071N0 SLEEVE 0715 '%A' 11200' ' p.el3• LD.) ' T1W SBR (12 bn0) 11255 CS~e' PACKER TOP OFTLINER TIW (HBBP-R) It277 ' 11335 Y ]-12 , 9.21A1 LdO. TAILPIPE 0•Si6', 17/AL NTOSHS, NSCC 11685 -~~ P RFn ~TN VI T T1W 'Na~BP' PKR tu~Awv C RN. L00: OLLGR ry2ye21 WI }12•,X, NIPPLES 12~6T (2.750' MN D) AL 111111 006 VNK 2 V0' VNI ~ 123V'. 127!? PGi~ 2180'- I2no ~TM1Y WIED 12905 IMa( 0d 0NK 210' ~ 277P-12796 2MD'•Ib7o OT1S 1V0' PKR W17.12'X'AND 12715 F- 'XN• NIPPLES . F- Tn'7 WLEO 1275T ' OT1S 1YD' PKR _ W72-72"%'AND 7lN' 12600 ~- NIPPLES E-- z-776•wtEO Izen• Para 1]I97 T, 291AL I-00. aua 132!0 LY1/1 Date By Comments FNDICOTT W ELL: S-02~SD-10 7/w1e0 Jltl COMPLETION API NO. 50-029-20640 COMPLETION DIAGRAM BP EXPLORATION, INC. QQgg pp ~~pp 5 - 02 / S O -10 - soots-2os~ot L•EOIiNPpEN0ILQ88 OliEU90, ttN1i1~8• tSi LOGt OLL 23-FEB-B Prs:lna-4n nEN~7~CQl;AL,(~GS - STRRTIGRRPHIC M~ PRF/FF/CEK 160 ( 0 N O . ~..,. -. _ . O . .~. N N ___ .:.?; o ~„ : N ' O _ ~ __ . ..,. c..,.:.. N .: :: N .Nr C .....:..:.. ;~ ._. ..[... o• ., ` ~ o .551) t• _. -r J IJECTION INTERVAL, - ` - ;._. N Q _ '-- ~ N ~fC 2 2 199 .DDO~ ~/ K o Alaska. Oil RA Gas Cons. CommiS~iOn Ancl~Orage WELL NAME LOG/DATE GONE TOP M.D. BOT M.D. H TOP TVD BOT TVD SPINNER SPINNER SPINNER SPINNER 3/30/88 9/1 1 /88 3/1 1 /90 5/5/90 5-02/SD-10 DIL/SFL 2A3 12650 12730 80 10110 10170 1.00 0.48 0.43 0.55 3/23/82 2A1 12770 12795 25 10200 10220 0.00 0.52 0.57 0.45 2A1 12840 12870 30 10252 10275 0.00 0.00 0.00 0.00 • • [\ N O~ O~ z N N 0 o •~ ~n \ ~-~/'~ W W CO O I`~ O N > r- N l.(~ Ln ~ d- ~t d- I I .~.~ ~ ~ N N ~ ~ ~ ~ O O O O ~s7.sae 2si.75e :°~-_--J..___1 zs2,eae zsz.zsa zs2,sse zez.7se ze~.3ae zes,25A zes.see 1__,~l_ ...__J._J__ .L__L__.,1~1._-L_.__.L.~l. ~L:>~1 - zGS,7ss 259,e0~ __.L.__L ~.Lm ~ ~ 9 ) ~. S ~ d s ~ 9 S ~°•, r_~ ~ ~ .t ~ i m y I m~ I iJ ~ ~ V~ ~~ , , ;~ P 2tLt ~ / CO~~ ~ ~ N m ~ • j~ ~ ro ~ m m ~' ~ P~ L180 Lt8 ~ m ,~ / ~ . ~, d ~~p_2 ~- 0 S -~ '; m m J m :, ~, '~~.. o ~ O ~4 / ~ ... ~ .,~ ~ w gar ,, 1 ~ ~~ n .° ~, m i ~C \ O;y~ILfB X ~ ~~ h .~ ~• b `' N , • ~` ,~ m Y J v W O O !.- m v . m fG ~ ~ a y ` >:6Q m QVP ~ 3 J J cl! m N 0 m _ r--~-T --i X1.580 2E1.78@ [82.fl08 262r25B 292.583 262.750 293.8flfl 2fi3.2 26 0,,-24 Pilot/Horizontal Well D&C Proposal Top 2B Depth, Top 2M faults •~ ~ .~ N N m \ m b r ~ m m N a m N __ zss.vs~ zE9.ee~ 40 • BP EXPLORATION November 28, 1994 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL_ DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99 51 9-6 61 2 (907) 561-5111 As I discussed with you this morning, BP Exploration (Alaska) Inc. requests written authorization to flare a total of 30 MMcf of natural gas at Endicott as early as November 29, 1994. This flare request is associated with performance testing of both main gas compressor trains. Both the main gas compressors at Endicott have recently been repaired. The additional flare volume requested is for approximately six days of performance testing of these repaired gas compressors. If you have any questions concerning this request, please contact me at 564- 4838. Sincerely, Alison D. Cooke ~E~~IVEG ~~Y 2 9 1994 ~)eska uu ~ Gas Cons. Commission Anchora~# $k39 ~ ~ BP EXPLORATION June 17, 1994 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ~_ BP Exploration (Alaska) Inc. 900 East Benson Boulevard ~ / P.O. Box 196612 '~~( Anchorage, Alaska 99519-6612 (907) 561-5111 __ ENDICOTT FLARE REQUEST /~~ ~ oZ , 3 S r ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. requests written authorization to flare a total of 20 MMcf of natural gas at Endicott as early as June 23, 1994. This flare request is associated with repair work on a main gas compressor recycle valve. A leak in the instrument air supply to the 1st stage "B" Main Gas Compressor anti-surge valve actuator was discovered on June 14. A temporary fix has been implemented to repair this leak. It is anticipated that a permanent repair can be completed within 2 hours, pending parts delivery. To complete the repair, the instrument air supply must be disconnected. The valve will then fail open, resulting in flaring for the duration of the repair. The total flared volume will not exceed 20 MMcf. Exact timing for this repair work is uncertain. Parts are expected to arrive at Endicott on June 23. We anticipate completing the repair not later than the week of July 4, and will attempt to schedule this work to coincide with any production slowdown in the interim which would allow us to avoid flaring. If you have any questions concerning this request, please contact me at 564- 4838. Sincerely, Alison D. Cooke ~~~C1 V ~~ JUG! 2 2 1994 ~~+uska ~Jii ~ Gas Cores. Commission ~nchora~c Mr. Russ Douglas'3!AOGCC Page 2 6/17/94 bcc: Endicott Field Manager Endicott Operations Superintendent Endicott Production Coordinator S. Repp J. Platt M. Davis N. Weiss File: PC-DIU/AQ/Flare Request RECEIVED JUN 2 2 1994 ~~iaska r~if & Gas Cons. Commission Anchorage ~ 3~ • BP EXPLORATION June 3, 1994 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. requests written authorization to flare a total of 180 MMcf of natural gas at Endicott associated with the performance testing of the Main Gas Compressors. Performance tests of Endicott's Main Gas Compressors will be conducted with the assistance of Nuovo Pignone test engineers from June 9-17. We expect to flare approximately 20 MMcf/d for the nine days of testing. The nature of these tests is similar to the emissions testing which took place following the Main Gas Compressor Upgrade Project in 1993, and is neccessary to troubleshoot and optimize the performance of the equipment, thus increasing oil production. During the testing, the compressors must be operated at multiple load points while holding the speed constant; this is accomplished by flaring a portion of the gas at the lower loads. This procedure is then repeated at several different compressor speeds. During the testing it is not a practical alternative to cut gas rates to avoid flaring. If you have any questions concerning this request, please contact me at 564- 4838. Sincerely, o..~.~~„ ~ . c..., Alison D. Cooke rt~r-` : BP Exploration (Alaska) Inc. , ; 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RECEIVE U ~ - 6 1994 ~(asi<a Uil & Gas Cons. Commission Anchorage a7~ • BP EXPLORATION March 25, 1994 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ~t7~• ~~ BP Exploration (Alaska) Inc. G 900 East Benson Boulevard /~~'1/ P.O. Box 196612 ~i JJi/ ~J Anchorage, Alaska 99519-6612 "~ (907) 561-5111 3 I '~~f "y~~ ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. requests written authorization to flare a total of 400 MMSCF of natural gas on or about March 26, 1994. The flaring may be necessary during repair operations on both the "A" and "B" Main Gas Compressors (MGC). Both of Endicott`s Main Gas Compressors will be taken down this weekend (one at a time) to ensure the mechanical integrity of the MGC system. This inspection will ensure we do not have a repeat occurrence of the recent MGCA 1st stage impeller damage. MGCA will go down Saturday (3/26) to repair the GLT block valve and boroscope 2nd stage. MGCB will go down Sunday (3/27) to boroscope both 1st and 2nd stages. Evaluation of the remains of MGCA's 1st stage indicate a potential erosion problem that could manifest itself again in either or both of the Mains. Each operation is scheduled for approximately 15 hours and will require 200 MMSCF of flared gas per event. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, ~~~~ . ~~ Alison D. Cooke RECEIVE MAR 2 9 1994 ~~sska i~it & bas Cans. commissiar~ Anchorage `J L: i.i~t v u `~`J ~. u"L :.~ u U ~' ,-! L: i~ ,. ~ WALTER J. HlCKEL, GOVERNOR ALASKA OIL AA'D GAS t 3001 PORCUPINE DRIVE CO1~ SER'~'A'~'IOlI' COMMISSIOl~ r ANCHORAGE. AUISKA 99501-3192 PHONE: (907) 279-1433 • 7ELECOPY: (907) 27Cr7542 ENVIRONMENTAL March 25, 1994 APR 0 8 1994 & REG. AFFAIRS ADMINISTRATIVE APPROVAL NO.202.33 Re: .Additional flare volume, Endicott .Oil Pool production facilities, Duck Island Unit. Alison D. Cooke BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Ms. Cooke: We have received your letter of March 25, 1994 requesting additional flare volume for the Endicott oil pool production facility in the Duck Island Unit (DIU). The additional flare volume is required during repair operations on the A and B main gas compressors. The Commission hereby approves flaring up to 400 MMcf of gas over and above. the designated safety flare of the Endicott production facility. Flaring is expected to commence on or about March 26, l 994 and continue until work is complete. It is understood that gas flaring will be kept to a minimum whenever possible, and all volumes will be reported monthly on Alaska Oil and Gas Conservation Commission form 10-422. All gas produced in excess of the l 200 Mcf/d safety flare volume is subject to AS 43. X5.020, and will be disposed of in a safe manner by flaring or used for lease operation. sincerely, C> Russell A. Douglass Commissioner B1' ORDER OF THE COMMLSSION 5/1 0/94 8P EXPLORATION (ALASKA) INC. Page 2 ADMINISTRATIVE APPROVAL NO. 202.4 GAS FLARING INCIDENT REPORT - ENDICOTT Aprll-94 >'«<:>:::QA'['E .:::;:::.;;:«::.:>:<::::'t~11E.....; :........... ........Y4E.~v1E::::.; ::>:.>::»:~t~I~#I~'114?..~~:1NGI~~~!1'I'.>~..~'rl!-ttSIR>:<:::>:::<::.... .. . .aA........+~I~.T~EE~.T'.t~.>~4,.~#..~!IA'I'NR:...AUG....:...........:::::::.:.:: Apr 19 1036-1038 233 Plant upsets as production was increased Adjusted production or gas compression system as 1556-1600 following TAPS startup necessary to stop flaring Apr 20 1931-1951 660 Daily test of flare header Completed flare test Apr 21 2113-2142 6,036 Both MCs slowed to minimum to permit Completed calibration and returned to normal calibration of 1st stage suction flow compressor operation. transmitters in conjunction with flare test A r 22 2030-2037 P 750 Dail test of flare header Y Com leted flare test P Apr 23 2003-2012 1,545 See above See above Apr 24 1947-1953 901 See above See above Apr 25 1435-1503 900 See above See above Apr 26 1558-1627 268 See above See above Apr 27 1733-1753 1,599 See above See above Apr 28 1959-2006 983 See above See above Apr 29 1917-1924 1,257 See above See above A r 30 2033-2042 1 179 See above See above p , :::::>:: ...... >::>:::>::T~3TAL`:>~:::::: ................................. ::>::»::><:>:::>:>'<:><:><<:::<:<:<:::>'::::>::>:»:>:»:::>:::>':><::>>:?<:::»»:SDr~>s':>': ' .....................................................................................::::::: ><>~~>'>::::<:>::::»»~:::::>«:::s:>::>~:::>..EN ...f;J! :................................. :::::...................................................::::::. .. ::: ~::::............................. Volume flared in excess of 50,237 13 2 ~J o 05 , measured safety pilot/purge Measured safety piloVpurge 40.655 ~,2 40.596 TOTAL FLARED VOLUME 90,892 191 90,701 y ' 5/10/94 BP EXPLORATION (ALASKA) INC. Page 1 ADMINISTRATIVE APPROVAL NO. 202.4 GAS FLARING INCIDENT REPORT - ENDICOTT April-94 <:: ::............................ ................................:::::::::: :::::::.:..::......:.:............. ......, ........................~'''1'ft~.?~....Ili+~ll~~'I'.&.....15~»:>:<::: :<, :.. ... >:...:. r: .~. U ... Apr 1 1927-1932 604 Daily test of flare header Completed flare test Apr 2 1942-1947 645 See above See above Apr 3 1835-1841 652 See above See above Apr 4 1828-1833 684 See above See above Apr 5 1839-1845 646 See above See above Apr 6 1844-1850 .595 See above See above Apr 7 1957-2004 1,01 1 See above See above Apr 8 0022-0259 10,688 Both main compressors S/D. HHL fuel Restarted both compressors gas KO drum Apr 9 2050-2100 894 Daily test of flare header Completed flare test Apr 10 01 17-0213 6,530 "B" main compressor S/D, false THH alarm Restarted "B" main compressor 1943-1954 Daily test of flare header Completed flare test Apr 11 1941-1952 928 Daily test of flare header Completed flare test Apr 12 0746-0758 1,138 See above See above Apr 13 1957-201 1 1,125 See above See above S Apr 15 0202-0207 812 Plant upset occurred while slowing down Process was brought under control 0221-0224 production due to a TAPS planned rate reduction Apr 17 1848-1853 2,475 Daily test of flare header, "A" MC returned Completed flare test, and optimized production to 1904-2013 to service and production was increased to prevent flaring the gas handling capacity of the compresso r Apr 18 0630-0647 4,499 Prod. gas rate higher than anticipated Cut prod. gas to stop flaring. Increased rate in 2215-2324 when "B" MC S/D for maint.. Intermittent smaller increments to prevent flaring as wells flaring as prod. increased following TAPS gassed off startup X36 L~ BP EXPLORATION February 23, 1994 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP Exploration (Alaska) Inc. requests written authorization to flare a total of 100 MMSCF of natural gas on or about February 24, 1994. The flaring may be necessary during additional repair operations on the "B" Main Compressor. After changing out the actuator on the "A" Main Gas Compressor 3rd stage recycle valve we found that significant adjustments had to be made to the air control system, which required additional work not anticipated in our flare request of February 21, 1994, which the commission approved on February 22, 1994 (A. A. 202.31). We anticipate that this additional work will be required on the "B" compressor and ask for the additional flare volume to complete this work. If you have any questions concerning this. issue, please contact me at 564- 4838. Sincerely, o~~,'~. cam., Alison D. Cooke ~ECEIVE[~ f=~~ %~ ~ 1.9G4 . ;a Ci ~ Gas Cons. Commission Anc"Drags ~ 35 February 21, 1994 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 • ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. requests written authorization to flare a total of 100 MMSCF of natural gas on or about February 22, 1994. The flaring may be necessary during repair operations of valves on both Main Compressors. A recent repair to the 3rd stage anti-surge valve on the "B" Main Gas Compressor was successful. The valve now remains closed during normal operation. However, upon receiving an open signal, this "B" Main valve will "hammer" between settings of ~10-40%. Repair work will likely require a limited compressor shutdown. The 3rd stage anti-surge valve of the "A" Main Gas Compressor is indicating a continuous 6% open position. Inspection and repairs to this valve may also result in a limited shutdown. This repair work may require the compressors to be taken out of service for a combined total of approximately 12 hours. Exact shutdown timing will depend on parts availability and vendor representative scheduling. If you have any questions concerning this issue, please contact me at 564-4838. Sincerely, t~ GND/co7T ~itnvu cn ca/ . ~ E ~ E ~ Y E !.~ Alison D. Cooke ~t.i~ ~ ~ 1J~~ ,;';,~:~,se~ ~;i ~ Cas Cons. Commission Anchorage ~~ M BP EXPLORATION February 3, 1994 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: r BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP Exploration (Alaska) Inc. requests written authorization to flare a total of 100 MMSCF of natural gas on or about February 6, 1994. The flaring will be necessary during repair operations of a valve on the B-Main compressor. The 3rd stage anti-surge valve of the "B" Main Gas Compressor is sticking open approximately 14% of the time. These repairs will require the compressor to be taken out of service for approximately 12 hours. Exact shutdown timing will depend on parts availability. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, v Alison D. Cooke RECEIVED ~E8 °' 7 1994 Alaska Gil & Gas Cons. Commission Anchorage ~ 33 • BP EXPLORATION October 19, 1993 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. requests written authorization to flare a total of 100 MMSCF of natural gas on or about October 19, 1993. The flaring will be necessary during operations to "water wash" the power turbine blades on the B-main gas compressor to improve pertormance. The washing will require the compressor to be taken out of service for approximately 10 hours. The work could be done as early as today if the opportunity presents itself. Otherwise we will schedule the work on or about October 22 and plan to have the work completed on or about October 25, 1993. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, ~~, ~ . <.,..0>2 0 , Alison D. Cooke ~ T~ ~,, ~~ ~ ~~9 ~i'astca.(~(1 & %as Gvns. t~arr~rx)i~s)~~ ~nc~ora~a ~' 32 • BP EXPLORATION September 17, 1993 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. requests written authorization to flare a total of 15 MMSCF of natural gas on or about September 18, 1993. The flaring will be necessary during operations to repair a leaking flange on the well head of gas injector 1-15. We will need to flare while the i-15 injector well is out of service because our gas injection capacity will be limited. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, ~~~~ ~ ~~ Alison D. Cooke /~/~ /~ ~~ ~~ Alaska tall & bias ions. Gorr~~~issio~j Anchorage ~ BP Exploration (Alaska) Inc. ~/y ''y.7 900 East Benson Boulevard '" P.O. Box 196612 VL.tf-~- Anchorage, Alaska 99519-6612 (907) 561-5111 ~~~ 1~ BP EXPLORATION July 8, 1993 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: ,,;C3~19 .Of~/E BP Exploration (Alaska) Inc. ~~-.~ ~~~ 900 East Benson Boulevard -~~ ESC P.O. Box 196612 ~~ ~~G Anchorage, Alaska 99519-6612 (907) 561-5111 ~~~ Asd E'=~`da AS~ CCEOL ~~OL ASSTS TAT TECH I S~'A7 TECH 1 BP Exploration (Alaska) Inc. requests verbal and written authorization to flare a total of approximately 500 MMSCF of natural gas at Endicott, commencing July 8, 1993. Flaring is necessary during repair of a main compressor valve, which failed on the night of July 7, 1993. Valve failure caused a gas leak inside Module 302. The system was immediately shut down. Approximately 120 MMSCF per day of gas will be diverted to the flare while repairs are made. Flaring should be completed on or about July 12, 1993. We would appreciate verbal approval at your earliest convenience. Please contact Carol Klein at 564-4079 or Steve Repp at 564-4505. Sincerely, Davi Lowe, Ac ' g Supervisor Environmental Compliance, Alaska ~1 ~ U L ~ 3 ~~3 Alaska Oil & Gas Cons. Comr~issi~~ Aaclinragel ~ 3Q • BP EXPLORATION June 24, 1993 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: u BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP Exploration (Alaska) Inc. requests written authorization to flare a total of 80 MMSCF of natural gas on or about June 28, 1993. The flaring will be necessary during operations to flow back the new. Endicott gas injector 1-15. We estimate that to clean up the perforations and optimize infectivity we will need to flow the well back to the facility for two days at a rate of 40 MMSCFD. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, Alison D. Co--oke ?~ c ~CL~~~Cl~ ~1 U~ ~ $ X993 Alaska Oil & Gas Cons. Commision Anchorage 29 BP EXPLORATION June 17, 1993 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 EN~T'1" FLARE REQUEST. ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ~~ ivz.z~ On May 4, 1993, BP Exploration (Alaska) Inc. (BPX) requested a written authorization to flare a total of 4320 MMCF of natural gas at Endicott associated with two shutdowns to implement Endicott's Main Gas Compressor Upgrade Project. The AOGCC issued Administrative Approval 202.24 for these shutdowns. BPX have completed the first of these two shutdowns. Original projections of the duration of days necessary to complete the scope of work involved with each shutdown were optimistic. Instead of the18 days we projected, the work took 21 days for the first shutdown. We did however maintain approximately the estimated flare volume of 120 MMscf/day. We expect the second shutdown will also take 21 days and ask the AOGCC for authorizarion to flare an additionai 360 MMCF to cover the three additionai days.. The second shutdown could begin on or about June 21, 1993. Please call me at 564-4838 if you have any questions concerning this flare request. Sincerely, Alison D. Cooke ~~EI~J ~ ) ~~"c ~;~ L ~~ ,1 U ~ 2 2 ~~9~ Alaska ~til ~ Gas Cons. Commissio~~ Anchorage ~'~2$ BP EXPLORATION May 4, 1993 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 t~TT n-FLARE FiEQUESI ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ,vIVIM I ®M ~cS ~~ N~ ~~ ~R ENS ~ E~~ ASST ~~~! ,4G SST S~ G~®L ~EQ1. A~ ~~~~ FC~l S~~`!1~'" ~TR1' TIC.-i - BP Exploration (Alaska) Inc. requests written authorization to flare a total of 4320 MMCF of natural gas at Endicott associated with the shutdown of the A- Main Compressor Train from May 24-June10, 1993 and the shutdown of the B-Main Compressor Train from June 21-July 8, 1993. These two shutdowns are to implement Endicott's Main Gas Compressor Upgrade Project, which will increase gas handling capacity by approximately 75 MMSCFD. The workscope associated with these shutdowns include installation of Advanced Technology Parts (ATP) in the Main Compressor turbines to increase horsepower, rewheeling the compressors themselves to increase throughput (reinjection), replacing piping to route gas through new heat exchangers to increase interstage cooling, replacement of recycle valves, and installation of new internals in interstage knockout drums. Anticipated duration of this work is eighteen days for each train with an approximate flare volume of 120 MMscf/day. Certain high GOR wells will be shut in to minimize flaring, and we do not anticipate any black smoke flaring due to the smokeless design of Endicott's flare. Alternatives to flaring these gas volumes include reducing Field Gas Offtake to the capacity of a single compressor while the other train is being modified. Deferred production for this alternative would be approximately 825 thousand barrels of oil compared to 405 thousand barrels for the flared gas option. e~ ~~ - ~, "s~93 :~las3ca ~iil & Gas Gans. Cornmissio~ Anchorage Mr. Russ Do ~, AOGCC Page 2 5/4/93 If you have any questions concerning this request, please contact Alison Cooke at 564-4838. Sincerely, Steven D. Taylor, Manager Environmental & Reg latory Affairs, Alaska SDT/ADC ~ECEI~ED ~ ~ - ~ ~~~~ Alaska Oil & Gas Cons. Commission Anchorage 27 ~ t BP EXPLORATION March 24, 1993 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL QUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP Exploration (Alaska) Inc. (BPX) requests written authorization to flare a total of 300 MMSCF of natural gas for approximately two days during the last two weeks of April. The flaring will be necessary during the shut-down of each Main Gas Compressor (MGC). Each MGC will be shut-down for approximately one day for cleaning to prepare for the MGC upgrade work this summer. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, 0.4.~.a~,``~ ~ ~.s~x.~•Q. Alison D. Cooke ,q~ao2.a3 ~ 26 BP EXPLORATION March 22, 1993 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 t BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ENDICOTT FARE REQUEST ADMINISTRATIVE APPROVAL _QLLG,I~~ 1~L~1ND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. (BPX) requests written authorization to flare a total of 175 MMSCF of natural gas on or about March 22, 1993. The flaring will be necessary during operations to tie-in the injection line for the new Endicott gas injector 2-12/Q-16. To safely make the connection to the gas injection header, the system must be depressured and we will be unable to inject produced gas back in to the reservoir. The connection will require flaring the full produced gas stream for approximately 12 hours. This request is in addition to the volume approved in Administrative Approval 202.20 for flaring during the perforation of injector 2-12/Q-16. These modifications will permit future gas injector 1-15 to be connected without the need to flare. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, ~~,~ . (~ Alison D. Cooke Y A~ ~ a~9 ~iaska ail & has ions. Gom~aissia Ancitoragei ~~ t BP EXPLORATION March 4, 1993 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 FNDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL [~.~LAND {~{iT Dear Mr. Douglass: BP Exploration (Alaska] fnc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP Exploration (Alaska) Inc. (BPX) requests written authorization to flare a total of 48 MMSCF of natural gas on or about March 4, 1993. The flaring is necessary due to the shutting down of the B-booster compressor for motor repairs. The motor must be sent out for repairs and therefore the need to flare could last up to 12 days. We will attempt to keep flaring to a minimum. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, Alison D. Cooke ~~ ~~~ . ~ ~ 1 ~~~ PEAR -- ~ ~~93 Alaska Oi{ & Gas Cons. Carr:r~{ssi~~y Anchorage # ~4 C: BP EXPLORATION February 24, 1993 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. (BPX) requests written authorization to flare a total of 165 MMSCF of natural gas on or about March 30, 1993. The flaring will be necessary during pertorating operations on the new Endicott gas injector 2-12/Q-16. The well will be backfiowed to reduce hydrostatic pressure. Perforating underbalanced is a standard practice to help reduce formation damage caused by debris from the pertorating. Backflowing also helps clean up the pertorations for increased infectivity. _t ~ r. ~/~ The flowback of 2-12 will be to the 1st stage separator. Because our plant is already limited by gas production, the additional volumes produced from gas injector 2-12 will need to be flared. Timing of this event depends on when the drilling of 2-12 is complete and the flowlines are connected. Based on drilling time of 35 days and 3 days for line hookup, the flaring could occur as early as March 30 but is more likely to occur in April. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, Alison D. Cooke ~~~~ord~~s c°~i ~#"~s%ir # 23 BP EXPLORATION February 4, 1993 Mr. Russ Douglass Alaska Oil and .Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 M BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TT FLAB€ REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (BPX) requests written authorization to flare a total of 180 MMSCF of natural gas commencing on or about February 8, 1993. One of Endicott Field's three gas injector wells, 2-06/J-22, must be shut in for approximately 48 hours due to the close proximity of drilling. Drilling will be done at well 2-12/Q-16 which is a critical injection well. When it is out-of- service, Endicott will not be able to inject all produced gas even with a number of high GOR wells shut in. BP Exploration (BPX) requires written notification of administrative approval for planned flaring to satisfy Department of Revenue requirements and to avoid paying a penalty on gas produced in excess of the safety flare volume. If you have any questions concerning this issue, please contact Kate Purl at 564-4043 or Alison Cooke at 564-4838. Sincerely, ~~ .Steven D. Taylo , M Hager ~~ ~ Environmental & Re ulatory Affairs, Alaska ~.~~s~~ '~~`~ G,f ~~~ ~ ~a ~'~ ~ °~~r`~9~ ~0rrr ~~s'~~°~ r' .. ~~ ~" ~ 22 BP EXPLORATION January 12, 1993 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ~;~ti~Esd ~a~R~ "Qi47Nl ;:~.5 LNG aR ~PVG fiE~L A~ ~ ;e4~t~~. A~~ - - - ----- --- - -- i ~T T'CCH BP Exploration (Alaska) Inc. (BPX) requests written authorization to flare a total of 160 MMSCF of natural gas on or about January 12, 1993. The flaring will be necessary to repair four fin fans. The repair work is expected to last about four days. These repairs are in preparation for the main gas compressor upgrade project, which will be implemented this summer at Endicott. If you have any questions concerning this issue, please contact me at 564- 4838. Sincerely, Alison D. Cooke ADC "$~~ ~t~Fw:£~ ~s~ ~"'; ~~"' ~+:l~~x tiui'tf11~t5S9Cr~ M # 21 ~ ~~ ;~ ~ ~ d ~ ~ ~ ~ ~ ~ ' ~`~~ ~ i ' ~ ' ~~~~ I ~ ~ ~~ ~~ ~ ALASKA OIL A1~TD GAS COl~SER~TATIOlY COMMI5SIOI~T December 31, 1992 Tim Tyler Manager, Endicott Development BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 ~~ WALTER J. NICKEL, GOVERNOR l r ~~ 3001 PORCUPINE DRIVE f ANCHORAGE, ALASKA 995013192 f PHONE: (90'n 279-1433 TELECOPY: (90~ 278-7542 Re: Extend the provisions of Administrative Approval 202.15 until permanent pilot gas volumes are assigned. Dear Mr. Tyler: We received your December 16, 19921etter requesting approval of a permanently assigned pilot gas volume of 1200 mcf per day for the Endicott Field. We have not completed our North Slope Flared Gas Study, now estimated at the end of February. When that study is completed, safety flare volumes will be assigned to all the North Slope facilities that now flare gas under our jurisdiction. Until that time, the provisions of Administrative Approval No. 202.15 will remain in effect. Sincerely, ~~,~ i . ' .% I / fir. Leigh Griffin Commissioner BY ORDER OF THE COMMISSION ~~o • BP EXPLORATION December 16, 1992 one U ~P Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 REQUEST FOR PERMANENT SAFETY FLARE VOLUME ENDICO T T PRODUCTION FACILITY Dear Mr. Johnston: ~~~3 -- '~e~liM ~~S ENS ~Fi LNG I ~ ~t~4( J~C~K.t~~ i '' ~~ GAO U~(3L A~~~T~~( C~~~l.. ~SS~~ j~d°t~'r_T~~~-R ~ - ~l°FaT 7~~H f In Administrative Approval No. 202.15 the Commission increased the safety flare volume of the Endicott Field, Endicott Oil Pool production facility to 1200 MCF per day. This approval however is only in effect until December 31, 1992. BP Exploration (Alaska) Inc. (BPX) requests that the Commission make this safety flare volume permanent. The Commission granted the increase in volume on June 29, 1992 based on data BPX submitted to the Commission at an April 27, 1992 meeting and in subsequent correspondence dated May 18, 1992. The permanent volume increase is now even more imperative to BPX since our discovery and disclosure that the actual calculated pilot, purge, and assist flare volumes were higher than historically reported. This disclosure was made in a meeting with Mr. Blair Wondzell, of your staff, on September 29, 1992 and subsequently summarized in a letter to him on October 2, 1992. If you have any questions please contact Alison Cooke at 564-4838 or Janet Platt, Compliance Supervisor, at 564-5501. Sincerely, J Stev D. Taylor, Ma ager Environmental & Regulatory Affairs, Alaska SDT/ADC cc: Blair Wondzell, AOGCC ~~ V Alaska ~!i ~ gas inns. Comn~issi~r~ Anchorage ~~9 r BP EXPLORATION November 12, 1992 Robert Crandell Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Bob, r BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 On November 6th you and I discussed the placement criteria for Endicott proposed well J-33. Attached is across-section to graphically show the geologic units in J-33 and 3-15/K-33. Additionally this letter is to provide you with more details on the placement of Endicott proposed well J-33. J-33 is planned as a Zone 2A producer with Zone 1 as a secondary target. As stated in the variance request letter, the J-33 wellbore will be approximately 450 feet at TD from 3-15/K-33. 3-15/K-33 is a high angle well deviated toward the north, so the top of Zone 2A in these two wells will be about 1250 ft. apart in map view. The top of the Zone 2A perforations (and top of the zone) in 3-15/K-33 are at 9993 ft. ss. J-33 will be drilled updip with the top of Zone 2A expected at 9900 ft. ss. Since there is no gas cap in the Zone 2A SDI fault block, the mechanism for recovery is waterflood. Placing well J-33 updip of 3-15/K-33 will enable us to produce the updip Zone 2A oil that is not producable from any existing wells. Proposed well J-33 is planned in the upthrown fault block south of the mid- field fault. This fault block is in communication with the rest of the SDI and there is complete transmissivity across the fault between 3-15/K-33 and J-33. The Zone 2A perforations in 3-15/K-33 are on the south side of the fault shown on the attached cross-section. The well 3-15/K-33 crosses the fault in Zone 1 so the Zone 1 perforations in 3-15/K-33 and J-33 will be in the same fault block. Since the Zone 2A permeability and sand thickness is so much higher than that of Zone 1, most of the production from 3-15/K-33 is from the Zone 2A portion of the well. J-33 main target is Zone 2A with additional upside benefits from Zone 1 production. Additionally, the Zone 1 production from J-33 will drain oil updip of the perforations in 3-15/K-33 Zone 1. If you have additiona( questions, please contact me at 564-4531. Sincerely, ~ , Katie Nitzberg 2771/KEN ~'~ • BP EXPLORATION November 5, 1992 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. David W. Johnston • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 -03/J-33 SDI Endicott BP Exploration respectfully requests an exception to Endicott Pool Rule 3 as contained in Conservation Order 202 in order to drill and produce proposed well 3-03/J-33 in the Endicott Pool from zones 2A/1 C/1 B. The distance between well 3-03/J-33 and existing well 3-15/K-33 is approximately 44i feet at TD in the Kekiktuk interval. Well 3-15/K-33 is a high angle/horizontal well in service as an oil producer in zone 2A and zone 1. Although well 3-15/K-33 is producing from zones 2A and 1 and well 3-03/J-33 will also produce from zones 2A and 1, the 3-03/J-33 well will produce from a different fault block updip structurally. As the 3-03/J- 33 well will be placed updip of 3-15/K-33, a significant amount of reserves can be recovered that otherwise would not be recovered by the downdip well 3-15/K-33. Attached is a proposed drilling program for well 3-03/J-33. For our planning purposes, a response by November 12, 1992 would be appreciated. The scheduled spud date for this well is December 20, 1992. The Application for Permit to Drill will submitted by November 18, 1992. Thank you for your assistance in this matter. Bottom Hole Locations: At TD in the Kekiktuk Interval: 3-03/J-33: 465' SNL, 2567' WEL, Sec 4, T11 N, R17E 3-15/K-33: 323' SNL, 2984' WEL, Sec 4, T11 N, R17E l~t~~P` - ~ ?~~ ~lask~ &~ii ~ has ions. Gom~issid~ Anchorage • Y s very tru , Paul Chan Drilling Engineer • RECEIVE NOV - 5 ~~~~ Alaska Oil & Gas Cons. Commiss~~~ Anchorage • • PROPOSED DRILLING AND COMPLETIQN PROGRAM WELL 3-03/J-33 (DID Ob'ective Well 3-03/J-33 will be drilled as an oil production well. Zones 2A and 1 are the primary objective.. The completion will be run at the time of drilling and will consist of a simple type assembly with isolation packer. Operation Execute a rig move and rig-up. Directionally drill surface hole with a 8.5 - 9.5 ppg mud system to 2700 feet TVDss. Run and cement 13-3/8" 68#1ft NT- 80CYHE buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Directionally drill 12-1/4" hole with a 9.0 - 10.2 ppg mud system to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1 /4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole with a 9.8 ppg mud system to TD. Run open hole logs. Run and cement 7" 29#/ft, NT-13Cr-80 liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to landing collar. Test casing and lap to 3000 psi.. Change over to NaCI packer fluid. Complete with a simple type assembly and Isola#ion packer. A subsurface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig.. Perforate well and run bond logs and gyro in 7" liner after rig release. Fluids incidental to the drilling of the well will be pumped down the 13-3/8" by 9-5/8" annulus of the well The 13-3/8" x 9-5/8" annulus will be freeze protected with anon-freezing fluid down to 2000 feet once the rig is released. ECE~VED C 11-4-92 ~ ~ ~ _ ~ ~'~~~ alaska0il & t~a~ Cons. Comm-s~ion Anchorage • . a_r r ,., ~ - h T1~~.1}r t'7~ ..."" "1 y :~A ~~.i.. o; j Nor • '~\ ~~~~ ~! ~\~ - ~ X992 ~Easka (7il ~ Gas Cons. Commission' Anwhorage ~~ ~~jaa~9~ x-17 p,y:. BP EXPLORATION • P.O. Box 196612 ! ~ ~~~ Anchorage, Alaska 99519-6612 ~ ~~ ~(*y~ (907) 561-5111 i ~~~ ~~~°r October 21 , 1992 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Endicott Key Well GOC Monitoring Program September, 1993 -October, 1994 Dear Sirs: _-__~ .. ~ .~'~: s~~ BP Exploration (Alaska) Inc. `'~~~ 900 East Benson Boulevard ~~~ ~~~ >~ Ca~® __ € ~~o~ A ~, ~~~"r'~i° °T°~ "s3 'E ZoZ ~„ O As specified by the Endicott Field Rules, BPX (Alaska), Inc. is providing the results of the Key Well GOC Monitoring Program covering the period from September, 1993 thru October, 1994. We have carefully evaluated all information gained through this program and have documented important conclusions regarding field performance and reservoir trends observed over the past year. Based on current and past years results, for both Key Well Programs, BPX recommends the programs be adjusted from a five to a four well program. A specific request to remove key well 2-04/M-19 will follow at a later date, under separate cover. As in past reporting years, Endicott Development would welcome review of these data with the AOGCC. Please contact Mr. Bob Metzger at 564-4613 to arrange a presentation and discuss this material at your convenience. Sincerely, -Ellis Armstrong Manager, Endicott Develop rrm Enclosures (8) RECEIVED fVOV _ 3 i994 A4aska Oif & Gas Cons. Commission Anchora • • Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 cc: Endicott Subsurface Team bcc: Files 71.20A 06.10 RECEIVED NOV ~ 3 1994 Alaska Oil & Gas Cons. Commission Anchors, Endicott Oil Field GOC Monitoring Key Well Program September, 1993 -October, 1994 A Key Well Gas -Oil Contact Monitoring Key Well Program was submitted for the Endicott Field in October, 1988 one year after field start-up in accordance with AOGCC Conservation Order 202, 9(c). At that time, BP Exploration sought, and received a waiver (Administrative Approval Order 202.5) from the State of Alaska, to initiate the key well program for Endicott on a subzone basis for each of the three distinct reservoir development areas of the field. Administrative Order No. 232.1 provided an exemption for key well GOC monitoring in Sections 1, 3, 7, 9, 10, and 35 of the field as being outside areal gas cap limits of the reservoir. Four of the five key wells continue to provide useful gas-oil contact movement information, as gathered through time lapsed cased hole neutron logging. This report summarizes the findings of the sixth year of the Key Well GOC Program between September, 1993 and October, 1994. During this report period, a total of 15 cased -hole pulsed and compensated neutron logs (PNL /CNL) were acquired, including the five key well surveys. This represents an increase of 4 cased hole neutron logs over the 1992 - 1993 program. The increase was due to diagnosing cement channels and identifying aquifer /gas movement. Table 1 lists the current five key wells and details the cased-hole PNL and CNL surveys acquired during the report period. Note the use of the CNL is precluded in all wells except 1-27/P-20 due to size restrictions of down-hole completion equipment employed at Endicott. The table also summarizes GOC movement ; and gas influx by underrunning major shales within Subzones 3A and 2B. Minor '~' movement of the original gas cap was verified through the use of the PNL /CNL in two of the key wells (see time lapse logs attached). In 1994, the rate of gas ,~ cap movement was mitigated through effective subzone offtake management and waterflood pressure maintenance. DECEIVED NOV _, 3 1594 ~taska Uif & Gas Cons. Commission Anchora • • Key wells to monitor gas movement in the 2A (MPI) and 3B / 3C are not practical due to the close proximity to gas and complex stratigraphy (shaliness), respectively. In both cases, it is highly doubtful time lapse logging would provide meaningful data with respect to regional GOC movements. The key well program for Endicott is based on the understanding of a limited ability to monitor fieldwide, original gas cap movement. A scarcity of wells and limited lateral offset from gas severely restricts the use of time lapse cased-hole logging as a viable tool to predict gas movements at Endicott. It is recognized that narrow hydrocarbon corridors caused by a relatively steep 6 degree structural dip combined with sands separated by thick laterally continuous shales promotes underrunning as the dominant gas influx mechanism. In addition to the continuous shales that separate the reservoir into six vertically isolated subzones, major east-west trending fault offsets provide either lateral hydraulic isolation or partial pressure communication between the three main Endicott development areas. Gas underrunning shales remains a dominant mechanism in a majority of the ~ %~ high GOR wells at Endicott. Underruns of major shale sequences in the 3A, 2B, and 2A have been identified by production logging, down-hole mechanical isolation of perforated intervals, or inferred through detailed reservoir shale correlation and proximity with the original GOC. During 1993 - 1994, low GOR production capacity was depleted, beginning along-term trend towards higher producing GOR's. In addition to the five key well cased hole neutron logs, 10 additional cased hole neutron logs were run within the reporting period to identify GOC movement, aquifer movement, Sor changes, and cement channels. The Endicott GOC Monitoring Key Well Program has been successful in establishing baseline and repeat PNL / CNL surveys to monitor and document rates of gas cap movement and gas underruns in the five key wells. Production logging and down-hole mechanical isolation of gas prone intervals has also provided a means at Endicott to monitor gas influx. Together, these tools constitute an effective means to monitor gas at Endicott. ~, E C G ~~ L ~OV ~ 3 1994 ~~~~~ ~~~ ~ Gas Cons. Commission Anchora • • BPX recommends that the 1995 GOC Key Well Program for Endicott be reduced by one well, omitting Well 2-04/M-19 from the Program. By inspection of the attached 2-04/M-19 Sigma porosity, gas cap expansion has completely moved through Subzone 2B. Gas underrunning of Subzone 2A3 is complete. Little utility is seen in continuing to run a PNL in this well on an annual, scheduled basis. A specific proposal to omit 2-04/M-19 from the agreed program will be sent to the Commission under separate cover. The remaining four key wells continue to provide optimal locations to evaluate GOC movement in the MPI and Niakuk 3A and 2B subzones. E~EI V G~ ~y - 3 1994 ~.fca U;1 ~ has ~~ns, ~omnnis~i~n ~lnchnr~ 1993 - 1994 Endicott PNL / CNL Surveillance Loaaina 3-11 /M-30 11 /02/93 P N L 1-21 /K-25 11 /27/93 P N L 3-25/M-27 12/01 /93 PNL 2-50/U-08 12/03/93 PNUBORAX/PITS 1-05/0-20 02/04/94 C N L 1-39/P-17 02/06/94 PNL 2-22/L-14 02/07/94 PNL 1-45/Q-26 05/19/94 PNL 2-16/M-16 05/20/94 PNL 1-39/P-17 05/30/94 RST 2-04/M-19 07/09/94 PNL'` 1-01/J-19 07/28/94 PNL* 1-29/M-25 07/29/94 PNL* 1-09/J-18 07/30/94 PNL'' 1-27/P-20 07/31 /94 PNL'` * Key Wells • ~ECEIVEa ~iOV _' ~ 194 i~4dSKa Gil & Gas Cons. Commission ,Anchor ENDICOTT OIL POOL GAS OIL CONTACT MONRORING PROGRAM STATUS REPORT- OCTOBER 1994 TABLE 1 WELL GOC SUBZONE DATE OF BASELINE MONITOR SURVEYS 1 1-01 /J-19 2B 31-Jan-89 2~lan-90 NM, GUR (2A3) 13-Feb-91 GCX (5') ,GUR (2A3) 31-Jan-91 GCX (4'), GUR (2A3) 29-Mar-93 NM, GUR (2A3) 28-Jul-94 NM, GUR (2A3) 1-09/J-18 1-27/P-20 ~ 1-29/M•25 3A 3A 28 ii.lan-88 29-Feb-88 3-Feb-88 14Jan-88 21-Feb-87 3-Feb-88 NM NM (OHCNL) f GCX (25')/GUR(2B3) 1-Feb-89 9-May-88 8-Aug-88 GCX (4'),GUR,(265) NM ~ GCX (16') 14Feb-90 4-Aug-88 ~ 6-Aug-89 GCX (10'), GUR(265) NM, GUR (2B3) ~ GCX (7') ::~ 24Feb-91 12-Apr-89 5-Sep-90 GCX (T), GUR (2B5) NM,GUR (2B3) GCX (8') 16-Mar-92 17-Jun-90 25-Mar-91 GCX (5'), GUR (265) NM, GUR (2B3) GCX (4') 22-Aug-93 4.lu1-91 17-Mar-92 GCX(2'), GUR(2B5) GCX (7'), GUR (2B3 / 3A2) GCX (16') 30-Jul-94 13-Jun-92 ~ 24May-93 NM, GUR (2B5) GCX (9'), GUR (263/3A2) ~ GCX(15), GUR(2A3) 26-Jun-93 29•Jul-94 GCX(8'), GUR(3A2) ~ GCX (13'}, GUR (2A3) 2-04/M-19 3-01 /N-29 2B 3A/2B 1-Mar-88 28-Feb-88 1-Mar-88 19-Feb-89 GCX (25') NM 20-Mar-89 12-Feb-90 GCX(35'), GUR (2B2) NM 16-Jun-90 28-Feb-91 GCX(4'), GUR (2A3) NM 29~1un-91 NO LONGER A KEY GCX (NM), GUR (2A3) WELL AS OF DEC. 9 14Jun-92 GCX (2'), GUR (2A3) 25~Jun-93 NM, GUR (2A3) 9-Jul-94 NM, GUR (2A3) 2 3 4 5 6 7 v> ~ Qo ~ I''T~[ g ~ ~ p C~.i us o 9 3 c ,~ m 3 31-Jul-94 GCX (2'), GUR (2B3) RRM 10/19/94 • i NM = NO GAS CAP MOVEMENT GUR =GAS UNDERRUN (STRAY. SEQ.) GCX =GAS CAP EXPANSION (FEET TVD) ENDICOIT KEY W ~ 1 -01 /J- i 9 MD SIG RUN 6 ORM sio RuN I PHI RUN 6 (FT IBH/CPNL;2 IGM/CPNL;I PPHI/CPNL: 150 0 22 7 40 SIG RUN S GRM sic RuN PHI RUN 5 IBH/CPNL;2 ICM/CPN L;1 PPHI/CPNl;1 150 O 22 40 . SIG RUN 4 ORM SIO RUN 4 PHI RUN IBH/CPNL;1 IGM/CPNL;1 PPHI/CPNL:1 150 O 20 5 40 NL POROSI SIG RUN 3 oRM sw RuN PHI RUN 3 NPHI/CNL;1 IBH/CPNL:1 IGM/CPNL:1 PPHI/CPNL;1 60 O 150 0 20 5 40 CR CPNL EN91TY roROS SIG RUN 2 ORM sio RuN PHI RUN 2 GR/CPNL:2~ PHIT/DENS;1 IBH/CPNL;1 ICM/CPNL:I PPHI/CPNL;1 O 15~ .60 O 150 O 20 5 40 PEN HOLE G ~• PERFERATION SIG RUN 1 CRM SIC RUN ~ PHI RUN 1 GR/COMB;1 - PERF/FLAG;1 IBH/CPNL;1 IGM/CPNL;I PPH1/CPNL;1 O 15 a g O 150 O 20 5 40 ^ SCALE , . GAS Sf i i l sas ~ j t ~ f t ~ 1 r ~ 2M ~ ~ ~ 4AJ uae i ~ ,, ' .f ~1 .-~ ~I 1 1 I' 1 .em i i I t ~ l ~ J I ~ 1 ; I ~ , t i S ~ .~ .,~ f i 1 • RECEIVED tVOV ~~ 3 1994 ~11~SiC1 Gii & Gas Cons. Commission Anchors '„tOI~~U~ Chit' uo~ss±WU~o~ •suo~ s~~ ]~ t!l~ ~~.~ Y V 61 ~ .+ i \ ~ ~~ ~~ ~~~~~ t :i ~S ;• •..f 1 1 1 J I, l exit i .: 1 f ZBL s ~ S t. ~t z ~, f ~ ti i 1~ IYC i 1 1 1 ~ s ~ ~ t ~ ~ S ess ~ sw ~ 1 1 1 i 1 i 1 s 1 1 `~ L f s b i S V ~ ~1 oerss ~ ,7 h s~a3d ~I ~ ob l~~NdO/IHdd z Nna IHd 04 L7lNd0/IHdd £ Nna IHd o~ L~lNdO/IHdd 4 Nna IHd Oti l'~NdO/IHdd S Nna IHd Ob l~~NdO/IHdd 9 Nna IHd O~ l~~NdO/IHdd 9 Nna IHd oz l~lNd~/WOI Nna OI5 wao OZ L11Nd0/W`JI Nna ols wao oz L~"1Nd0/W`JI Nna oit wao OZ l~~NdO/W'JI Nna ois wao OZ l~lNdO/WeJI Nna ols wao £Z t~~NdO/W91 Nna ois wao o osL L'~NdO/HBI Z Nna OIS O OSL L•~NdO/HBI £ Nna OIS o osL L"lNdO/HBI {. Nna JIS O OS L~INdO/W`JI g Nna OIS ~ yQ b s L'0`d'ld/da3d - "^O1^1OA1~ 09' - L%SN30/llHd soaod I.lISN3 os L~~NO/IHdN I50!!Od '1N ~ SL o l~BW00/a0 s O 3'lOH N3d - SL O Z~nNdO/a0 nNdo ao B L -('/60- L ~1 M J.~yl 110~IaN? ENDICOTT KEY L 1 -27/P-20 PNL GR/CCNL;2 O 15 ~ PEN HOLE. G GR/COMB;1 O 15 0 ORO51 NPHI/CNL;1 60 O ENSIIY POR09 PHIT/DENS;1 ~ .60 O MD (FT NL eIOMA a IBH/C PN L;1 150 PHl RUN 7' NPHI/CCNL;1 42 PHI RUN 6 NPHI/CCNL:1 42 PHI RUN .5 NPHI/CCNL;1 .4 PHI~RUN 4 NPHI/CCNL:1 40 PHI RUN 3 NPHI/CCNL;1 40 .................... PHI RUN 2 NPHI/CCNL;1 40 PHI RUN 1 NPHI/CCNL:1 40 aSCALE , GAS r ; j~ S - l ,,,z L~ ~ r .. _ _ ~ °s ,_ «~ 5 ' r 'S ~ - >, L - i ~~ Zee r ~• ze: ~ - _ _ _ _ _ ,: ~ - - - = - = - = - ,~ . _ _ _ N IIM ~~. f ~ r:., ..~ r c: ~ • 'E'T'V E i~~~s ~6€ ~ Gas Cony. commission .Anchork ENDICOTT KEY ~ 1 -29/M-25 PNL GR/CPNL:2 0 15 - OROSI NPHI/CNL; 1 60 eNSix ronos PHIT/DEN5; .60 MD (FT 1 O G RUN $ IGM/CPNL; 50 SIG RUN 3 IBH/CPNL;1 150 SIG RUN 2 IBH/CPNL;1 150 oRM mo RuN IGM/CPNL;I 22 RM SIONRUN IGM/CPNL: 22 oRM sio RuN IGM/CPNL:1 20 ORM s10 RUN IGM/CPNL; 1 20 ORM slo RuN ICM/CPNL;I 20 RM sio RuN ICM/CPNL;1 20 RM sio RuN IGM/CPNL;i 20 PHI RUN 8 PPHI/CPN L;1 40 PHI .RUN 7 PPHI/CPNL; 40 PHI RUN 6 PPHI/CPNL: 40 PHIY RUN 5 PPHI/CPNL; 40 PHI RUN••4 PPHI/CPNL; 40 PHI RUN 3 PPHI/CPNL; 40 PHI RUN 2 PPHI/CPNL: 40 PEN HOLE c +a GR/COM B;1 - 0 15 0 .iwm+e. PERF/FLAG; 6 1 0 SIG RUN 1 IBH/CPNL;1 150 ORM sw RuN + ICM/CPNL;I 20 PHI RUN 1 PPHI/CPNL; 40 PERFS + . ~ f . rw , .' i,. S ~ i t, t ~ > ; 't ~' t I , s ~ J+ ,~. 3M i •'. ZA t t +1 ' I nro ~ T .o i, t i • ~~~~~~ ~~ 'V~~ ~. ~ 9a3~°'F ~ ~~:~~a ~Et ~ Gas Co~~. Commission ~~~char: ENDICOTT KEY •L 2-04/M-19 CPNL GR/CPNL;2 O 15 - POROSI NPHI/CN L; 1 60 cNSix voROS PHIT/DEN5;1 .60 - O MD (FS IG RUN 8 IGM/CPNL; 50 SIG 'RUN 5 IBH/CPNL;1 150 SIG RUN 4 IBH/CPN L:1 150 SIG RUN 2 IBH/CANL;1 150 oRM s.o RuN ICM/CPNL;I 22 oRM 5~0 RUN IGM/CPNL;I 20 RMYS~G RUN IGM/CPNL;I 20 ORM sio RuN IGM/CPNL; T 20 ORM SAC RuN IGM/CPNL;I 20 PHI RUN 8 PPH1/CPNL; 40 PHI ,RUN 6 PPH1/CPNL;1 .4 PHI RUN 5 PP H1/CPN L;1 40 PHI RUN 4 PPHI/CPN L;1 40 PHI RUN 2 PP HI/CPNL;? 40 PEN HOLE O t GR/COM 8;1 O 15 e - PERFORATION PERF/FLAG: 6 O SIG RUN 1 IBH/CPN L:1 150 ORM sic RUN t IGM/CPN L;I 20 pHl RUN 1 PPH1/CPN L:1 40 ® PERFS 1 .~ ~~~ l ~ ~ r, 7M C f- - _ I w ^. L \, l ~, i ;~ t i t 2wa _ i i •f i . ~ awt a I ~~ . :, , - - I r' - ~ ; • ~~~~~~ ~~ ~OV -~ ~ ~~J~~ ,~~~. Ui4 ~ Gas Co-~~. Go~-t~iss-QR ,Ar-chor X16 • r _.,~„ BP Exploration (Alaska) Inc. ':~_G_~~~ 900 East Benson Boulevard ~G~~M Po. Box isssl2 DES ENG Anchorage, Alaska 99519-6612 SR ENG (907) 561-5111 SR ENG ENG ASST 'ENG ASST sR GEOLG July 10, 1992 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: EQL ASSTi~k? _~.-r~~ T~c~ I BP Exploration (Alaska) Inc. (BPX) requests written authorization to flare a total of 92 MMSCF of natural gas on or about July 24, 1992. The flaring may be necessary during the plant shutdown associated with the causeway breach work and subsequent plant startup. The plant shutdown is expected to last four days. To minimize flaring, production wells will be brought back on gradually to decrease the chance of equipment shutdown. If we go into a flaring situation, production from high GOR wells will be cutback to reduce the flare volume. If you have any questions concerning this issue, please contact Alison Cooke at 564-4838. Sincerely, I Steven D. Taylor, Man er ~ Environmental & Regul tory Affairs, Alaska ~, SDT/ADC J U ~.. ~ 4 Alaska iii & has boas. ~ammissan { Ancllarage ~~~ • BP EXPLORATION May 18, 1992 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Sirs: ~~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP Exploration (Alaska) Inc., as operator of the Endicott Field, requests that the safety flare limit be increased to 1200 MSCF per day, modifying the existing provisions under AA No 202.. ~ Summarizing, the requested increase is premised on: 1) Increased overall gas handling volumes 2) Further projected increases in gas volumes 3) Documented safety flare incidents 4) Loading of single processing facility. Attached please find the supporting basis for the request, as presented to the commission on April 27, 1992. If you have any questions, please contact Steve Repp or Ron Shook, on 564- 4505 and 564-4832. Sincerely, ..._.__I ~~-, Tim Tyler Manager, Endicott Development R~'CEI VED ~~ ~ s ~~2 ~faska Oil & Gas Cons. Anchorage Commission 2598IRAs Endicott Safety Flare Background/Summary 1. In the Field Rule Testimony (August 22, 1984) pp 39, SAPC requested a safety flare volume of 500 mscfd per month. 2. SAPC wrote to AOGCC on Feb 13, 1987 requesting safety flare of 125 mscfd (purge gas 72 mscfd + pilot 18 mscfd +anti-diffusion 23 mscfd + 10%). This was granted under AA No 202.2, issued Feb 20, 1987. 3. After 5 months operation, a request was made in Aug 1987 to increase the safety flare limit to 400 mscfd. Reasons for request were - Excess flare volumes occurred in 2 of the 5 months reported - Total gas flaring over this 5 month period averaged 250 mscfd (ie excess flare averaged 125 mscfd) 4. To further support the case, it was cited that - Endicott's safety limit was the most restrictive amongst N/S fields, based on ratio of facility gas handling capacity to safety flare limit. An increase to 400 mscfd will put Endicott closer in line with other N/S developments a o a ~ ~ tTg ~~ ~ o ~' ~ ~ ~ ~.. ~" c7 to 3 ~ n"( vi y O Apra 27, 1992 - AOGCC cvx Endicott Safety Flare Limit Increase Endicott is requesting an increase to the existing safety flare limit from its current 400 mscfd (effective August 1988) to 1,200 mscfd. The following are the background and basis to the request :- • Despite careful and safe operations throughout 1991, Endicott has recorded 22 flaring incidents. 18 out of the 22 incidents were unplanned, caused almost entirely to equipment malfunction and inclement weather (snow drift). There has been no evidence of flaring improvement during 1 Q 92. • Actual gas handled during 1991, including Endicott and Sag North produced and gaslift gas amounted to 67,200 mmscf (184 mmscfd). Reservoir management strategy developed during year end 1991 significantly increased gas handling rates at the end of the year and into 1992. Excess gas flared during 1991 amounted to 147 mmscf or 400 mscfd average. Of this excess gas, 87 mmscf (60%) were unplanned flaring and 60 mmscf (40%) were planned flaring. • Current Endicott facility gas handling limit is nominally 400 mmscfd. A MGC Upgrade Project is scheduled to be stazted up 3Q 1993 which will increase the limit to about 443 mmscfd. • Projected gas handling increase from 1991 to plateau gas rate in 1994 are Year Facility Gas Handling ~ Annual Gas Rate % Increase Limit (mmscfd) ~ (mmscfd) to 1991 Rates 19 91 4 0 0 0 ~ 184 (actual) - 19 9 2 4 0 0 ~,, ~° ~ ~ 267 (projected) 4 5 1993 400/443 ~ ~ `~ ~ 384 (projected) 109 1994 onwards 443 ~ ~ ~ ,~ 443 (projected) 140 ~ ~ o C 3 N r°~'1 April 27, 1992 - AOGCC 3 ~ cvx a • Endicott Safety Flare Limit Increase • Basis for increasing safety flare limit from 400 to 1,200 mscfd relies on: a) 1991 flare statistic b) Projection of actual 1991 annual average gas handling rates to 1994 gas handling plateau rates c) 3 mmscf bi-weekly flare test required for safety/equipment protection - Total and excess gas flared in 1991 = 236 mmscf and 14? mmscf respectively. - 60% excess gas flares in 1991 was due to unplanned events. - 1994 gas handling is projected to be 2.4 times that handled during 1991. Projected total gas flared in 1994 = 236 * 2.4 = 566 mmscf - Projected excess gas flared in 1994 =Total gas handled -Current safety flare limit = 566 - (236 - 147) _ 477 mmscf - Unplanned portion of excess flare at approx 60% = 477 * 0.6 = 286 mmscf - Proposed bi-weekly flare test for safety/equipment protection (assuming 9 months per annum) = 3.0 (52/2) * (9/12) {mmscf*weeks * (weeks/year)} = 58.5 mmscf/year Requested safety flare limit = (Unplanned portion excess flare) + (Current safety volume) + (Bi-weekly Test) = 286 + (236-147) + 59 = 434 mmscf/yr = 1.20 mscfd (rounding) April 27, 1992 - AOGCC cvx Endicott Proposed Safety Limit Compared to Other N/S Fields Field Facility Gas Handling Capacity (mmscfd • PBU Field 5,300 • KRU Field 4 6 5 Lisburne Milne Point Endicott (Existing) Endicott (proposed) Safety Flare Limit (mmscfd~B 10.3 465 ~ o tZ8 440 __ ~ ~ ~ ; 8 0 ~ ~ ~' rn o ~° ~N ~ C 400 ~ ~ ~ rn 443 ~ ~ ;~ (i) Post smokeless flare installation. 0.9 up to 3.3 (~ ) 1.0 0.25 0.4 1.2 Ratio Comments A:B 515 GHX-1 .gas handling rate. Safety Flare Limit from: FS-1,2,3 @ 1.0 mm ea GC-1,2,3 @ l.lmm ea CGF @ 3.0 mm CCP ~a 1.0 mm Total = 10.3 mmscfd 517 Existing safety limit from: CPF-1 & 2 0.25 mm ea CPF-3 0.4 mm Total = 0.9 mmscfd to 140 Possible proposal (KRU evaluating) 440 320 Z , 0 0 0 Endicott most restrictive 370 • • April 27, 1992 - AOGCC cvx Endicott Flaring Incidents in 1991 Date VoI Duration Rate Comment (mscf) (Hrs) (mmscfd) 01/21/91 17,892 5.5 78.1 Planned -Repair 3rd stage disch v/v on MGC'A' 01/29/91 1,000 5.7 4.2 Unplanned - Entire facility s/d due to snow drift to generator air inlet filters 01/30/91 21,000 8.3 60.5 Unplanned - per above snow drift but MGC could not be re-started, plugged air filters 02/03/91 4,000 1.0 96.0 Unplanned - MGC'B' tripped 02/07/91 2,000 12.0 4.0 Unplanned - Snow drift plugging air filters. 02/08/91 1,333 8.0 4.0 Unplanned - Continuation of 02/07/91 event 03/06/91 13,100 7.5 41.9 Unplanned - MGC'A' nozzle linkage problem followed by MGC'B' WHRU damper failure 03/08/91 13,500 5.0 64.8 Planned -Gas injection v/v repair 05/13/91 1,166 0.6 48.0 Unplanned - MGC'A' WHRU v/v position problem 05/25/91 4,748 2.8 41.4 Unplanned - MGC'A' fuel supply solenoid failure. 1st stage separator relieved to flare 05/30/91 5,200 5.5 22.7 Planned -M GC load sharing mods conducted 06/06/91 6,125 12.2 12.1 Unplanned - SDI slug shut production and tripped one compressor. On restart, power surge caused other compressor and all but one generator to trip 06/07/91 19,125 1.7 267.3 Unplanned - Contination of above 06/18/91 8,000 3.S 54.9 Unplanned - PLC failure caused emergency plant S/D and compressor trip 06/21/91 500 1.5 8.0 Unplanned - High ambient temp (75F~. Booster comp s/d on high disch temp. Intermittent flare, assist gas used to avoid black smoke. 07/21/91 2,500 0.4 150.0 Unplanned - Both MGC tripped to idle. 1st stage separator overpressured and flared 07/25/91 500 0.2 49.9 Unplanned - PM on 3rd st cooling fans tripped MGC on high disch temp • • April 27, 1992. - AOGCC CvH 08/11/91 2,456 3.3 18.0 Unplanned - PLC failure 10/ 13/91 61,100 1 5 97.8 Planned -Replace discharge header valve 11/21/91 2,880 1.0 69.1 Unplanned - PLC Problem 11/22/91 14,720 6.2 57.0 Unplanned - Both Gas Compressors tripped, temp monitoring and electrical problem 12/28/91 33.509 ~,,$ 21.3 Unplanned - Booster compressor trip followed by dual compressor trip 236, 254 144.7 • There were 22 flaring incidents in 1991; 18 unplanned and 4 planned • Total flaring of 236,254 mscf amounted to 146,925 mscf excess flare (excluding safety flare allowance of 400 mscfd per month) • 87 mmscf of excess flare were unplanned events, representing 60% of total flaring incidents ~ _ ` ~ T'r7 O~ ~ rn ~~ N .v.~ "\ CO ` 6~~ , ~ A, i r ^.7 • April 27, 1992 - AOGCC cvx Endicott Flaring Incidents to End March 1992 Date Vol Duration Rate Comment (mscf) (Hrs) (mmscfd) 01/01/92 17,892 5.5 78.1 Unplanned - Compressor trip 01/12/92 2,778 11.0 6.1 Planned - B ooster compressor s/down to inspect/repair motor vibration 01/28/92 500 1.5 8.0 Unplanned - Booster compressor overloaded & tripped 02/06/92 375 1.5 6.0 Unplanned - Booster compressor tripped 02/14/92 325 1.4 5.6 Unplanned - Booster compressor tripped 02/16/92 325 1.5 5.2 Unplanned - Booster compressor tripped 02/19/92 422 0.2 50.6 Unplanned - One MGC tripped 02/20/92 9,516 2.2 103.8 Unplanned - Both MGC tripped 02/22/92 694 1.2 13.9 Unplanned - MGC tripped 02/23/92 611 2.4 6.1 Unplanned - Booster compressor tripped 03/02/92 253 1.2 5.1 Unplanned - Booster compressor tripped on KO drum high level 03/03/92 1,700 0.9 45.3 Unplanned - MGC tripped 03/05/92 176 0.7 6.0 Unplanned - Booster compressor tripped on KO drum high level 03/06/92 1,200 4.9 32.0 Unplanned - Booster compressor tripped, control problems 3 3 7 1.3 6.2 Unplanned - per above 03/09/92 246 0.8 7.4 Unplanned - Booster compressor tripped 0 3 / 12/ 9 2 1,100 1.5 17.6 Planned -Flare test, found ice plugs in 2nd stage HP 03/14/92 2,100 1.1 45.8 Planned -Fl are test post plug 0 3 / 18 /9 2 4 7 6 1.6 7.1 Planned -Flare blockage check • • April 27, 1992 - AOGCC cvx 03/24/92 4,437 1.6 66.6 03/30/92 3.900 ~$ 117.0 49,363 46.0 Unplanned - S/down MGC due to PSV 'O' ring failure Planned - Flare test proper • There were 21 flaring incidents in the first 3 months of 1992; 16 unplanned and 5 planned • Total flaring of 49,363 mscf amounted to 20,986 mscf of excess flare (excluding safety allowance of 400 mscfd per month) • 39 mmscf of total flare were unplanned events, representing 80% of total flaring incidents Annualizing the 3 months of 1992 unplanned excess flare rates gives ~39mmscf*(12/3)=156 mmscf, which is 156/87 = 79% up from 1991. Predictions were that 1992 unplanned flare would be only 45% above. One explanation to the higher than predicted number is that the gas han dling rate so far in 1992 is higher than projected due to a revised Reservoir pressure maintenance strategy where higher GOR wells are being produced and the need to conduct bi-weekly flare test to ensure ice blockage does not occur. 0 ~ ~ ~~ ~ ~~~ ti "~ ~`~7 to '''`~ N ~~ Q 0 • • April 27, 1992 - AOGCC cvx X14 • BP EXPLORATION April 1, 1992 AT n ,~ Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDTCOTT FLARE REQUEST ADMINISTRATIVE APPROVAL Dt )C;K ISLAND UNIT Dear Mr. Douglass: ~~ BP Exploration (Alaska) Inc. (BPX) requests written authorization to flare during regular tests of the flare system. The purpose of the testing is to ensure that the flare lines do not become plugged with ice or hydrates to the extent where back pressure to the knockout drum would cause an unsafe situation. We expect the testing to be required every two weeks during the winter months only. The duration of each test will be approximately 30 minutes and we expect the gas flare volume to be approximately 3 MMSCF per test. If you have any questions concerning this request, please contact Alison Cooke at 564-4838. Sincerely, Steven . Tay or, an ger Environmental & Regu tory Affairs, Alaska SDT/ADC ~~~ w ~ #~ y- 3 - 9 ~ . ~ ,R,,.~-~ ~--°-~- ~"~'-'. •~R- '""`~~ Alaska Oi{ ~ Gas Cons. Curnmissiar~ ~~.~,. ~,• ,u.o..: Arwcl~orage ~~ ./ a r®MM ps ~ x~OMM r~ES ENC BP Exploration (Alaska) Inc. ~~ ENG 900 East Benson Boulevard ~R ENG Po. Box 1sss12 LNG AS: Anchorage, Alaska 99519-6612 ~ ENG AS: (907) 561-5111 SR GEO! X13 • BP EXPLORATION February 18, 1992 Mr. Russell Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAtdD UNIT Dear Mr. Douglass: ~EOL ASST '».=t~~'~ ASS ~~i'~T TECH ~ <~'~"AT TECH f --` ~_ ~ i.r~~.i~„+~ BP Exploration (Alaska) Inc. (BPX) requests written authorization to flare a total of 50 MMSCF of natural gas on or about February 25, 1992 to February 28, 1992. The flaring will be to conduct a performance test on the flare to verify the computer model being used as part of a Main Gas Compressor Upgrade Project. To minimize flaring, BPX will only flare while process parameters are being recorded. The system will be returned to normal between test runs. If you have any questions concerning this issue, please contact Alison Gooke at 564-4838. Sincerely, Steven D. Taylor, M ager Environmental & Reg latory Affairs, Alaska SDT/ADC ECE~~VD Alaska Oil & Gas Cons. Commis5`-ot~ Anchorage • ~`aCJiW~Ni® BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 '~~_ (907) 561-5111 '.}~12 r BP EXPLORATION October 11, 1991 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 EM1IDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: n`~~ ~i~U rQ4. A ---- ~~._.. BP Exploration (BPX) requests written .authorization to flare a total of 80 MMSCF of na#ural gas commencing on or about October 12,1991. The flaring will be done during repair of the leaking third stage discharge manual block valve on the gas injection header. Location of this valve necessitates that all gas injection is shut in for the duration of the repair. It is anticipated that the repair will require approximately 12 hours. BP Exploration (BPX) requires written notification of administrative approval for planned flaring to satisfy Department of Revenue requirements and to avoid paying a penalty on gas produced in excess of the safety flare volume. If you have any questions concerning this issue, please contact Kate Purl at 564-4043 or Alison Cooke at 564-4838. Sincerely, Steven D. Taylor, Man r V 1 Environmental & R tory Affairs, Alaska KFP V ~ 1Ld Iask~ Oil & Gas Gans. Comm_issian A~cR~orage _ - BP Exploration (Alaska) Inc. ;.,.)~ 900 East Benson Boulevard ENG ~~ P.O. Box 196612 -,-,~ ~NG Anchorage, Alaska 99519-6612 _ (907) 561-5111 ~~~ LNG S ~~ A~~~ ~~~ t BP EXPLORATION October 7, 1991 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. David W. Johnston • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box. 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RECEIVED It Gas Cans. C~m~ ~`~+~t-Cb~g~ r. 2-54/Q-12 MPI Endicott BP Exploration respectfully requests an exception to Endicott Pool Rule 3 as contained in Conservation Order 202 in order to drill and inject into Zone 3A of proposed well 2-54/0-12 in the Endicott Pool. The distance between well 2-54/0-12 and existing well 2-44/R-12 is 577 feet at the top of the Kekiktuk. Well 2-44/R-12 is in service as a water injector in Zone 3C/3B/3A, but will converted to a Zone 3C/3B injector after the completion of well 2-54/0-12. As well 2-44/R-12 will be injecting into Zone 3C/3B and well 2-54/0-12 will be injecting into Zone 3A, there will be no interference between the two wells. The distance between well 2-54/0-12 and existing well 2-42/P-13 is 846 feet at the top of the Kekiktuk. Well 2-42/P-13 is in service as an oil producer in Zone 3C/3A, but will converted to a Zone 3C producer after the completion of well 2-54/0-12. As well 2-54/0-12 will be injecting into Zone 3A and well 2-42/P-13 will be producing from Zone 3C, there will be no interference between the two wells. Attached is a proposed drilling program for well 2-54/0-12. The Application for Permit to Drill is enclosed. For our planning purposes, a response by October 11, 1991 would be appreciated. The scheduled spud date for this well is October 15, 1991. Thank you for your assistance in this matter. 1 • Bottom hole locations at top of Kekiktuk: 2-54/Q-12: 632' SNL, 1562' WEL, Sec 35, T12N, R16E 2-44/R-12: 1073' SNL, 1934' WEL, Sec 35, T12N, R16E 2-42/P-13 389' SNL, 752' WEL, Sec 35, T12N, R16E Encl: Permit to Drill You s very trul Paul Chan Drilling Engineer X10 BP EXPLORATION April 22, 1991 Mr. Russ Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Douglass: BP Exploration (BPX) requests written notification of the verbal approval received the morning of March 8th by Alison Cooke in a conversation with Mr. Lonnie Smith, to flare a total of 20 MMSCF of natural gas on March 8, 1991. The flaring was required for safety during the maintenance on a leaking valve stem on a gas injection header. To minimize flaring, production rates were reduced and high GOR wells were shut-in. BP Exploration (BPX) requires written notification of administrative approval for planned flaring to satisfy Department of Revenue requirements and to avoid paying a penalty on gas produced in excess of the safety flare volume. If you have any questions concerning this issue, please contact Alison Cooke at 564-4838. Sincerely, ~~ l Stev n .Taylor, Manager Env' on ental & Regulatory Affairs, Alaska ADC U ~~~~ ~~ ~~ ;~ r "? ~ . , ,~:,,~: ~eui~lSl~xs~~i:. :: ~ ~- CJ BP EXPLORATION January 21, 1991 ~~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 <;~n< ~ i . ~ ~~ Mr. Lonnie Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Smith: BP Exploration (BPX) requests written notification of the verbal approval received the morning of January 21st by Janet Platt, to flare a total of 20 MMSCF of natural gas on or about January 21, 1991. The flaring is required for safety during the maintenance of a gas leak discovered this morning in a high pressure valve. We requested this action immediately to take advantage of a required slowdown on production rates implemented by Alyeska. To minimize flaring, production rates will be reduced and high GOR wells will be shut-in. If you have any questions concerning this issue, please contact Alison Cooke at 564-4838. Sincerely, Steven D. yl r, an ge Environmental & Regu atory Affairs, Alaska p ADC /~ ,~~`~ I ~~~ I~s~ .~~~ 2~ jq~l c~Q a~ ~$~iiss~q~ ;2. c~ 2 -_ ~$ • BP EXPLORATION December 31, 1990 Alaska OBI & Gas Conservation Comm~ss(on 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. David W. Johnston 3-25/M-27 SDI Endicott ~~~ !9Ia SEC ~~ ~~a~~~/~ ~ ~~~~ ~~s ~0ns. BP Exploration respectfully requests an exception to Endicott Pool Rule 3 as contained in Conservation Order 202 in order to drill and produce proposed well 3-25/M-27 in the Endicott Pool from subzone 263/281. The distance between well 3-25/M-27 and existing well 1-29/M-25 is 871 feet at the total depth for each well. Well 1-29/M-25 is in service as an oil producer in subzone 2A. As well 1-29/M-25 is producing from subzone 2A and well 3-25/M-27 will produce from subzone 2B3/2B1, there will be no interference between the two wells. Attached is a proposed drilling program for well 3-25/M-27. The Application for Permit to Drill has already been submitted. For our planning purposes, a response by January 2, 1991 would be appreciated. The scheduled spud date for this well is January 3, 1991. Thank you for your assistance in this matter. Bottom Hole Locations: At Total Depth: • BP Exploration (Alaska) Inc. " 900 East Benson Boulevard 4 P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 3-25/M-27: 4795' SNL, 4044' WEL, Sec 32, T12N, R17E 1-29/M-25: 5105' SNL, 4858' WEL, Sec 32, T12N, R17E s Yours very truly, ~~ C.R. Maskell Senior Drilling Engineer ~~ ~~~ ka,~~~ ~ ~ '~c sCQos I,q~~ ha~~a~ c~m~iss~~ • t PROPOSED DRILLING AND COMPLETION PROGRAM WELL 3-25/M-27 ~SD1~ Objective Well 3-25/M-27 will be drilled as an oil production well. Subzone 2B3/2B1 is the primary objective. The completion will be run at the time of drilling and will consist of a simple type assembly. Operation Execute a rig move to slot 3-25 and rig-up. Vertically drill 17-1 /2" hole to 1000 feet, then directionally drill to 2579 feet. Run and cement 13-3/8" 68#/ft NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out. casing and 5 ft. of new hole and conduct a formation leak-off test. Drill 12-1 /4" hole to the intermediate casing ppoint above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1 /4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1 /2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, NT95HS buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to landing collar. Test casing and lap to 3000 psi. Change over to NaCI packer fluid. Run CET/CBT/GR/CCL in 7 liner and gyroscopic survey from PBTD to surface. Perforate well underbalanced utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well and complete with a simple completion.. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPS. Install tree on wellhead and release rig. Fluids incidental to the drilling of the well will be pumped down the 13-3/8" by 9-5/8" annulus of the well. The 13-3/8" x 9-5/8" annulus will be freeze protected with anon-freezing fluid down. to 3.000 feet once the rig is released. PC 12-27-90 Imo` ~ 7 t BP EXPLORATION October 30, 1990 '" ~~ `., lF Z ~. ';ti td Uc~' ~ i :., a BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mr. Lonnie Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT BP Exploration (BPX) requests written authorization to flare a total of 25 MMSCF of natural gas on or about November 19,1990 to December 3, 1990. The flaring will be to conduct a performance test on the flare to verify the computer model being used as part of a plant de-bottlenecking study. To minimize flaring, BPX will only flare while process parameters are being recorded. The system will be returned to normal between test runs. If you have any questions concerning this issue, please contact Kate Purl at 564-4043. Sincerely, Steven D. Taylor, M Hager Environmental & Re latory Affairs, Alaska KFP ~~ • BP EXPLORATION October 24, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. Lonnie C. Smith 3-29/J-32 SDI Endicott __. .s ;~.~~ "~~~ 5 f~`a~~ ~ ~ 3.r I°~ BP Exploration had requested and received an exception to Endicott Pool Ruie 3 as contained in Conservation Order 202 to drill and produce proposed well 3-29/J-32 in the Endicott Pool from subzones 2A and 1. A spacing exception was granted for this well on May 25, 1990 "Administrative Approval No. 202.7". Since that time, the bottom hole location and target zones have been modified. The well is now planned as a subzone 2B producer. Therefore BP Exploration is requesting an exception for the new bottomhole location as described. BP Exploration respectfully requests an exception to Endicott Pool Rule 3 as contained in Conservation Order 202 in order to drill and produce proposed well 3-29/J-32 in the Endicott Pool from subzone 2B. The distance between well 3-29/J-32 and existing well 3-15/K-33 is 802 feet at the top of the Kekiktuk formation. Weii 3-15/K-33 is in service as an oii producer in subzone 2A. As well 3-15/K-33 is producing from subzone 2A and well 3-29/J-32 will produce from subzone 2B, there will be no interference between the two wells. Attached is a proposed drilling program for well 3-29/J-32. The Application for Permit to Drill will be submitted following the approval of this exception. For our planning purposes, a response by October 31 would be appreciated. The scheduled spud date for this well is November 5, 1990. Thank you for your assistance in this matter. ~~~~ Ci BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ~:C ~~ :~ ~~~~~~~ -~~~ -,~, Cry` ~ ~~ 190 '~aska lit & Gas Cons. G~m~is~~ttrt An~hbra~e • • Bottom Hole Locations: Top Kekiktuk: 3-29/J-32: 1953' SNL, 4596' WEL, Sec 4, T11 N, R17E 3-15/K-33: 2092' SNL, 3806' WEL, Sec 4, T11 N, R17E Yours very truly, ~° C.R. Maskell Senior Drilling Engineer • u PROPOSED DRILLING AND COMPLETION PROGRAM WELL 3-29/J-32 (SDIa Objective Well 3-29/J-32 will be drilled as an oil production well. Subzone 2B is the primary objective. The completion will be run at the time of drilling and will consist of a simple type assembly. Operation Execute a rig move to slot 3-29 and rig-up. Vertically drill 17-1 /2" hole to 2500 ft. Run and cement 13-3/8" 68#/ft NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPS. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 2600 ft., then directionally drill 12-1/4" hole to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, NT95HS buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9- 5/8" casing. Clean out to landing collar. Test casing and lap to 3000 psi. Change over to NaCI packer fluid. Perforate well underbalanced utilizing drill pipe conveyed guns. Flow well for simple clean-u .Kill well and complete with a simple completion. A sub surface safety valve will be installed below base of permafrost. Nipppple down BOPE. Install tree on wellhead and release rig. Run CET/CBT/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Fluids incidental to the drilling of the well will be pumped down the 13-3/8" by 9-5/8" annulus of the well. The 13-3/8" x 9-5/8" annulus will be freeze protected with anon-freezing fluid down to 3000 feet once the rig is released. PC 10-23-90~ ~5 • BP EXPLORATION July 16, 1990 Mr. Lonnie Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENDICOTT FLARE REQUEST ADMINISTRATIVE APPROVAL DUCK ISLAND UNIT Dear Mr. Smith: BP Exploration (BPX) requests written authorization to flare a total of 100,000 MSCF of natural gas approximately August 1 through August 31, 1990. The flaring will be associated with shutdown and depressuring of the Endicott production facility for turnaround work, and then restart of the facility. To minimize flaring and black smoke, the high GOR wells will be the last wells shut-in and the first wells put on production. This will allow the gas- compression-injection system to operate as much as possible. If you have any questions concerning this issue, please contact Pam Pope at 564-5499. Sincerely, Steven D. aylor, Mana er Environmental & Regulatory Affairs, Alaska • 3 ~\.;. BP Exploration (Alaska) Inc. ~ i..' 900 East Benson Boulevard i ~, ,_ " E~ _. P.O. Box 196612 -- Anchorage, Alaska 99519-6612 ~ s.; _~F (907) 561-5111 '' ` . ., PRP ~ 4 I BP EXPLORATION May 21, 1990 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ~ ,r.T ~t~ ~~%' ~ ~~~ ~ ~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ 4~~ :. w :.F~,~; d~ gas ~or~~ ~`_ ~~. :~~~; Attn: Mr. C. V. Chatterton ~-nch~ra?~ 3-29/J-32 SDI Endicott I ~- P _. ~_ ~, ~~ ~r 7 ~S-ay-9n, rP~~ BP Exploration respectfully requests an exception to Endicott Pool Rule 3 as contained in Conservation Order 202 in order to drill and produce proposed well 3-29/J-32 in the Endicott Pool from subzones 2A and 1. The distance between well 3-29/ J-32 and existing well 3-15/K-33 is 914 ft for subzone 1 and 1281 ft for subzone 2A. Well 3-15/K-33 is in service as an oil producer in subzones 2A and 1. Well 3-29/J-32 subzones 2A and 1 is structurally updip from 3-15/K-33 subzones 2A and 1 and adds significant additional recovery that would not otherwise be recovered by the existing well. Utilization of both wells at this spacing maximizes recovery from the 2A and 1 subzones. Attached is a proposed drilling program for well 3-29/J-32. The Application for Permit to Drill will be submitted following the approval of this exception. For our planning purposes, a response by June 1 would be appreciated. The scheduled spud date for this well is June 22, 1990. Thank you for your assistance in this matter. Bottom Hole Locations: Top Subzone 2A: 3-29/J-32: 1113' SNL, 2607' WEL, Sec 4, T11 N, R17E 3-15/K-33: 1833' SNL, 3667' WEL, Sec 4, T11 N, R17E Top Subzone 1: 3-29/J-32: 948' SNL, 2524' WEL, Sec 4, T11N, R17E 3-15/K-33: 1224' SNL, 3395' WEL, Sec 4, T11 N, R17E Yours very truly, ~ Vt L M. E. Miller Endicott Lead Engineer r PROPOSED DRILLING AND COMPLETION PROGRAM ?YELL 3-29/.T-32 (SDI) Objective Well 3-29/J-32 will be drilled as an oil production well. Subzone 2A is the primary objective. The completion will be run at the time of drilling and will consist of a simple type assembly. Operation Execute a rig move to slot 3-29 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. Run and cement 13-3/8" 68#/ft NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 3500 ft., then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, NT95HS buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9- 5/8" casing. Clean out to landing collar. Test casing and lap to 3000 psi. Change over to NaCI packer fluid. Run CET/CBT/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Perforate well underbalanced utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well ,and complete with a simple completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPS. Install tree on wellhead and release rig. Fluids incidental to the drilling of a well will be pumped down the 13-3/8" by 9- 5/8" annulus of the well. The 13-3/8" x 9-5/8" annulus will be freeze protected with anon-freezing fluid down to 3000 feet once the rig is released. PC 5/21/90 ~3 BP EXPLORATION March 2, 1990 N ~~ ~ }4 au ~~ ~ C r _,.r ~~~. BP Exploration (Alaska) Ind 900 East Benson Boulevary P.O. Box 196612 Anchorage, Alaska 99519-6 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton 2-18/L-16 MPI Endicott BP Exploration respectfully requests an exception to Endicott Pool Rule 3 as contained in Conservation Order 202 in order to drill and produce proposed well 2-18/L-16 in the Endicott Pool 700 ft from existing well 2-16/M-16. Well 2-18/L-16 is designed as a subzone 3A producer. Well 2-16/M-16 is in service as a water injector in subzones 2B and 2A. subzones 2B and 2A are hydraulically isolated from subzone 3A, and utilization of both wells at this spacing maximizes recovery from the 3 subzones. Attached is a proposed drilling program for well 2-18/L-16. The Application for Permit to Drill will be submitted following the approval of this exception. For our planning purposes, a response by March 12 would be appreciated. The scheduled spud date for this well is April 3, 1990. Thank you for your assistance in this matter. Yours very truly, 1V4~ -~ M. E. Miller Endicott Lead Engineer RECEIVED l1,~AR - ~ ?9~t- Alaska Oil & Gas Cons. Commiss~o Anchorage ~~ ~J cc: Richard Loveland Richard Reiley Grant Vidrine 2-18/L-16 Wellfile #17 • RECEIVED MAR - ~ 199t1 Alaska Oil & Gas Cons. Commissio'~ Anchorage • PROPOSED DRILLING AND COMPLETION PROGRAM WELL 2-18/L-16 (MPII b'e iv Well 2-18/L-16 will be drilled as an oil production well. Zone 3A is the primary objective. The completion will be run at the time of drilling and will consist of a packer-tailpipe assembly. Operation Execute a rig move to slot 2-18 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. Run and. cement 13-3/8" 68#/ft., NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 5000 ft., then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, NT95HS buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9- 5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Change over to NaCI packer fluid. Complete with apacker-tailpipe completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Fluids incidental to the drilling of a well will be pumped down the 13-3/8" by 9- 5/8" annulus of the well. Once the rig is released the 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet. Additionally, aCET/CBT/GR/CCL will be run in the 7" liner, a gyro will be run from TD to surface, and the~y~l~v ~' be perforated with wireline conveyed guns. 1RC .. ~~ ~~-- KRL 2/2/90 LIAR ~ ~ 190 Comm~ssioc ~taska Oti & A chora9e my". LiVA ~.. ~ ~ BP EXPLORATION May 8, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 t n, ~r-.w;~_~,~~ - `~V ~~~i Jt's~ r-.~t~' Sri C=r,J- ASS ~~~T `I"~CI- Re: RFT Pressure Measurement Inclusion in Endicott Field Rule 6e s~~r s$~``'~~ ~~~..~.- Dear Sirs: This letter is intended to confirm the results of our April 24, 1989 meeting concerning the use of RFT pressure measurements in the Endicott Field. Following a presentation of our RFT program and a request for interpretation of Endicott Field Rule 6, it was decided that RFT measurements fully satisfy the static bottomhole pressure survey requirement set forward in Rule 6e. We will provide tabulated data at datum pressure and a plot of RFT pressure vs depth on future wells where RFT logs are appropriate. We will also calculate an average pressure for the producing horizon for reporting on AOGCC form 10- 412. Please direct any questions concerning pressure reporting to David MacDonald at 564-4697. Sincerely, T. N. Tyler Manager, Endicott Planning TNT/DGM/gjr cc: Working Interest Owners Files 6.10 & 6.20 ~~ T Standard Alaska Production Compan 900 East Benson Boule P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 12, 1988 1 /r ~ ~ 4J @~i ~ i~'J~ ~~' COi;~~,~ cc~!~r,~ - ~~s ~ -s ~~ r-A~r. Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton . ~ ~:;~Om ~ `~ `~ S ~::, E_ €016 "t; ~~' ~ ~~ a f'1 G ~tr38 I'°, vi t~ ._- ; . _- ~--.-. P..g~--~.__.__. In accordance with Conservation Order NO. 202 Endicott Field Rule 8 entitled "Gas Venting or Flaring," Standard Alaska Production Company as Operator for the Endicott Field requests authorization to increase its Safety Flare Volume allowance to 400 MSCFD. Standard is requesting this increase for facility safety purposes as discussed with the Commission on August 8, 1988. We appreciate the opportunity to review this issue with the Commission. Please contact Bruce Luberski at (907)564-5355 if you have any questions. Sincerely, A. Davies, Manager Endicott Development Planning A unit of fhe original Standard CAI Company Founded in Cleveland, Ohio, in 1870. s- ~ DARD KA PRODUCTION M a Reasons for Increasing the Allowance 1. Standard, as in the case of other North Slope Operators, views the Safety Flare Allowance to be used for maintaining pilot and purge functions and for the safe blowdown of equipment. 2. Compared to the Safety Flare Allowances of other North Slope fields, Endicott is the most limited. 3. Standard is operating as carefully as possible to minimize any flaring events but has exceeded the allowable limit 40% of the time based on reported flaring events. 4. Currently operating only one compressor train. 2nd train to be on line in 1-2 years. Endicott Safety Flare Permit 1. Current Safety Flare Permit is for an average of 125 MSCFD per month 2. Standard sent a letter to the AOGCC requesting a safety flare allowance of 113 MSCFD per month .based on pilot & purge gas only. The letter further requested an additional allowance for process upset conditions for. protection of personnel and equipment however noted that this was difficult to quantify at the time. 3. During the Field Rules Testimony Standard requested a Safety Flare Allowance of 500 MSCFD per month. • Actual Safety Flare Volumes 1. Actual Flare volumes reported over the last 5 months are based on normal operating conditions with 1 Main Compressor Train in operation. 2. These actuals showed excess flare volumes occurring in 2 of the 5 months reported. 3. Excess flaring averaged 125 MSCFD per month (which is 250 MSCFD per month less the current allowance of 125 MSCFD per month). • • Proposed Recommendation 1. Standard views this essentially as a revenue neutral issue however is concerned over the apparent inconsistency between safe operating practice and avoiding flaring penalties. 2. Based on reported volumes during single Main Compressor Train operation, the average Safety Flare Allowance should be 250 MSCFD per month. With 2 Main Compressor Trains operating we expect an increase of 70% or approximately 360 MSCFD per month. 3. Based on survey results of other North Slope operators with the average gas handling capacity divided by the average safety flare allowance, the recommended Endicott Safety Flare allowance is 400 MSCFD per month. Number of units 3 3 1 1 1 11 Survey of North Slope Production Facilities Gathering Center Flow Station Lisburne Kuparuk-CPF-1 Kuparuk-CPF-3 Milne Point Average N/S facilities Endicott A B A/B Gas Handling Safety Flare Ratio of Gas Handling Capacity Allowance in MMSCFD to Flare in ~MSCFD in MSCFD Volume in MSCFD 750000 1100 682 950000 1000 950 440000 300 1467 400000 250 1600 400000 350 1143 80000 250 320 620000 70p 886 400000 125 3200 • • FLARE VOLUMES FLARE INCIDENTS DURING 1988 Month Days Quantity (MSCF) Safety Flare(MSCF) Excess Flare(MSCF) March 31 13231 3875 9356 April 30 2397 3750 (1353) May 31 1130 3875 (2745) June 30 2420 3750 (1330) July 31 5701 3875 1826 Total 153 24879 19125 Average process 1 63 MSCFD (excluding pilot/purge) upset per day Pilot/purge 86 MSCFD Total per Day 2 4 9 MSCFD 8/8/88 • • Survey of North Slope Production Facilities Number of units 3 3 i 2 1 1 11 Gathering Center Flow Station Lisburne Kuparuk-CPF-1 Kuparuk-CPF-3 Milne Point Average N/S facilities Endicott Endicott-Recommended A B Gas Handling Safety Flare Capacity Allowance in MSCFD in MSCFD 750000 1100 950000 1000 440000 300 400000 250 400000 350 80000 250 620000 700 400000 125 400000 400 A/B Ratio of Gas Handling in MMSCFD to Flare Volume in MSCFD 682 950 1467 1600 1143 320 886 3200 1000 • • ~. _. Survey of North Slope Production Facilities Number of units 3 3 1 2 1 1 11 Gathering Center Flow Station Lisburne Kuparuk-CPF-1 Kuparuk-CPF-3 Milne Point Average N/S facilities Endicott Endicott-Recommended A B Gas Handling Safety Flare Capacity Allowance in MSCFD in MSCFD 750000 1100 950000 1000 440000 300 400000 250 400000 350 80000 250 620000 700 400000 125 400000 400 A/B Ratio of Gas Handling in MMSCFD to Flare Volume in MSCFD 682 950 1467 1600 1143 320 886 3200 1000 r •
