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Home My WebLink AboutCO 349 A• • 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: ,~wa=~ea miamiiiiuiin ^ Diskettes, No. ^ Other, No/Type: Date: Project Proofing BY Date: Scanning Preparation BY: x30= Date: ~ L' . ae,~~~~~eaea IIIIIIiIIVIIIIIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ p /s/ + =TOTAL PAGES~_ (Count does not include cover sheet) , ^ ' /s/ ~/ Production Scanning III IIIIII IIIII II III Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: ~ES NO BY: Maria Date: ~~ ~ g ~ g /s/ ~ p Sta e I g 7 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. II I II ~I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III III III 10/6/2005 Orders File Cover Page.doc • • INDEX CONSERVATION ORDER N0.349A 1.) May 6, 1981 BPXA request for an expansion of the order to include PBU KRU 2.) November 27, 1996 Notice of Public Hearing, Affidavit of Publication Conservation Order No. 349A ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF BP EXPLORATION ) (Alaska) INCo to amend the affected areas of ) the Prudhoe Bay Field, Kuparuk River Oil Pool ) as specified in Conservation Order No. 98-A ) and the Kuparuk River Field, Kuparuk River ) River Oil Pool as specified in Conservation ) Order Nos. 173 and 349. Conservation Order No. 349A BP Exploration (Alaska), Inc. Kuparuk River Field Prudhoe Bay Field Kuparuk River Oil Pool December 23, 1996 IT APPEARING THAT: BP Exploration (Alaska), Inc. (BPXA) submitted an application dated November 19, 1996 requesting expansion of the Kuparuk River Field, Kuparuk River Oil Pool affected area to include a portion of the Prudhoe Bay Field, Kuparuk River Oil Pool. Notice of opportunity for public hearing was published in the Anchorage Daily News on November 27, 1996 pursuant to 20 AAC 25.540. No protests to the application were received. FINDINGS: 1. The current boundary between the Prudhoe Bay Field, Kuparuk River Oil Pool (PBKROP) and the Kuparuk River Field, Kuparuk River Oil Pool (KRKROP) is described in Conservation Order (C.O.) No. 173 dated May 6, 1981. 2. Findings 3 through 6 of C.O. 173 document that the north western boundary of the PBKROP was delineated on the basis of structural trends projected into an area of relatively restricted subsurface control. 3. Finding 10 of C.O. 173 indicates that, at the time of~the writing, the KRKROP was anticipated to consist of a single pool with a common oil-water contact. 4. C.O. No. 349, issued December 16, 1994 modified the affected area and description of the KRKROP as put forward in C.O. 173. 5. Findings 4,6,7, and 12, and conclusion 1 of C.O. 349 document the KRKROP is composed of multiple separate oil accumulations caused by numerous pressure discontinuities related to extensive faulting and stratigraphic discontinuities. 6: Development drilling by BPXA in the vicinity of the Cascade 1 and lA exploration wells, within the PBKROP affected area, has established the presence of oil bearing Kuparuk River Formation which is structurally and stratigraphically equivalent to the KRKROP in Milne Point Unit. 7. The local eastern extent of this accumulation is established in the Arco Eileen #1 well located in section 7 T12N R12E U.M., which contained water saturated KRKROP equivalents. 8. BPXA intends to conduct Kuparuk River Formation development activities using Milne Point unit infrastructure with integrated KRKROP management procedures on State of Alaska oil and gas leases ADL nos. 28232, 375132 and 375133. Conservation Order No.~6A December 23, 1996 Page 2 CONCLUSIONS: 1. The boundary between the KRKROP and the PBKROP in the vicinity of the BPXA Cascade 1, lA and ARCO Eileen 1 wells was originally defined using limited subsurface control. 2. A oil accumulation common to the KRKROP has been demonstrated to extend into the PBKROP affected area in the vicinity of the BPXA Cascade 1, lA and Arco Eileen 1 wells. 2. Expansion of the KRKROP affected area in the vicinity of the BPXA Cascade 1, lA and Arco Eileen 1 wells is conducive to maximizing ultimate recovery of proved reserves and will not violate correlative rights. NOW, THEREFORE, IT IS ORDERED that Conservation Order No. 98-A is hereby amended by removing the following described area from the Prudhoe Bay Field Kuparuk River Oil Pool rules area. T13N, R11E, U.M. T12N. R11E, U.M. SECS. 27,34 SECS. 1,2,9,10,11,12 NOW, THEREFORE, IT IS ORDERED THAT the Kuparuk River oil pool rules area described in Conservation Order No. 349 is repealed and hereinafter pertains to the following described area: T9N, R6E, U.M. SECS. 1,2,11,12,13, and 14. T9N, R7E, U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, 14,15,16,17 and 18. T9N, R8E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,13, 14,15,16,17, and 18. T9N, R9E, U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11,12,15,16,17 and 18. T11N, R10E, U.M. ALL T11N, R11E U.M. SECS. 3,4,5,6,7,8,9,10,11,14,15,16,17,18, 19,20,21,22,23,24,25,26,27,28,29,30,31,32, 33,34,35 and 36. T12N, R7E, U.M. SECS. 25,26,35 and 36. T12N. R8E, U.M. ALL T9N, R10E U.M. SECS. 1,2,3,4,5,6,7,8,9,10,11 and 12. T12N R9E U.M. ALL T10N, R6E, U.M. T12N, R10E, U.M. SECS. 1,2,3,4,9,10,11,12,13,14,15,16,21, ALL 22,23,24,25,26,35 and 36. T12N, R11E. U.M. TION, R7E, U.M. SECS. 1,2;3,4,5,6,7,8;9,10,11,12;18,19, ALL. 20,29,30,31,32 and 33. T10N, R8E, U.M. ALL. T13N, R8E, U.M. SECS. 13,14,23,24,25,26,27,28,33,34,35' and 36. - - - ~~~~ Conservation Order No. ~A December 23, 1996 Page 3 T10N. R9E, U.M. T13N, R9E. U.M. ALL. ALL T10N, R10E, U.M. T13N, R10E. U.M. ALL ALL T10N, R11E, U.M. T13N, R11E, U.M. SECS. 5.6,7,8,17,18,19 and 20. SECS. 7,8,16,17,18,19.20,21,27,28,29,30,31,32,33 T11N, R6E, U.M. and 34. SECS. 25,26,35 and 36. T14N R9E U.M. T11N, R7E, U.M. SECS. 1,2,3,-4,5,6,7,8,9,10,11,12,13,14,15, SECS. L2,3,4,9,10,11,12,13,14,15.16, 16,17,18,20,21,22,23,2-1,25,26,27,28,29,32, 17,18,19,20.21,22,23,24,25,26,27,28,29, 33,34,35 and 36. 30,31,32,33,3-4,35 and 36. T14N, R10E U.M. T11N, R8E, U.M. SECS. 15.16,17,18,19,20,21,22,27,28,29,30, ALL 31,32,33,34 and 35 T11N, R9E, U.M. T15N, R9E U.M. ALL State lands «ithin SECS.. 25,26,27,31, 32,33,3-4,35, and 36. DONE at Anchorage. Alaska and da bcr 23, is ~ ~~~ ``'`~ ~~ ~~~~~~G Chairt an Da~•id W Johnston ,~ ~' J `' '`~ ~ ' . , ~ $ +~ ~ l and Gas Conscr< lion Commission Alaska ~,~ t, t~ . , a _. ~ ..- ~. ~~ ' V W 1. ~, V' ~ ckerman Babcock. Commissioner ~~ ~ ,, ti ~ ,, ~ u„~..~ ~; ,,~_ Alaska Oil and Gas Consen~ation Commission . ` ~ AS 31.05.080 provides that within 20 days after receipt of written notice of the entn' of an order, a person affected by it may file with the Convnission an application for rehearing. A reyuest for rehearing must he received by 4:30 p.m. on the 23rd day following the date of the order, or nett working day if a holiday or weekend, to be timely filed. "Ihe Commission shall grant or refuse the application in whole or in part within 10 days. The Conunission can refuse an application by not acting on it within the 10-day period. An affeMed person has 30 days from the date the Conunission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Conunission, to appeal the decision to Superior Court. Where a reyuest for rehearing is denied by nonaction of the Commission, the 30 day period fix appeal to Superior Court nms from the date on which the reyuest is deemed denied (i.e., 10th day after the application For rehearing was tiled). #2 ~J Notice of Public Hearing r~ L STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of BP Exploration (Alaska) Inc. to amend the affected areas of the Prudhoe Bay Field, Kuparuk River Oil Pool as specified in Conservation Order No. 98-A and the Kuparuk River Field Kuparuk River Oil Pool as specified in Conservation Order No. 173. The amended affected areas would expand the Kuparuk River Field, Kuparuk River Oil Pool as defined in Conservation Order No. 173 to include Sections 27 and 34 of T13N, R11E, UM and Sections 1, 2, 9,10, 11 and 12 of T12N, R1 lE, tJNf while deleting this area from the Prudhoe Bay Field, Kuparuk River Oil Pool as defined in Conservation Order No. 98-A. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM December 16, 1996 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 January 3, 1996 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 December 16, 1996. 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 December 30, ' ^^` Published November 27, 1996 A00271401 R ~# 1 • ~ ~ ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 Re: THE APPLICATION OF ATLANTIC ) Conservation Order No. 173 RICHFIELD COMPANY for a ) hearing to present testimony) Kuparuk River Field to determine the pool rules ) for the development and pro-) Kuparuk River duction of the Kuparuk River) Oil Pool. Formation west of the Prud- ) hoe Bay Field, The contrac- ) Prudhoe Bay Field tion of the Prudhoe Bay ) Kuparuk River Oil Pool and ) Prudhoe Bay Kuparuk Rive r the naming of the field is ) Oil Pool. considered as part of the ) application. ) May 6, 1981 IT APPEARING THAT: 1. Atlantic Richfield Company by letter dated November 25, 1980, requested the Alaska Oil and Gas Conservation Commission to take the nec essary steps to adopt pool rules for the development and production of the Kuparuk River Formation west and n orth of the. Prudhoe Bay Field. 2. Notice of a public hearing was published in the Anchorage Times on February 5,-1981. 3. A public hearing was held on March 25, 1981 at the Municipality of Anchorage Assembly Room, 3500 East Tudor Road, Anchorage, Alaska. Testimony was presented and oral and written statements were accepted. 4. The hearing was continued until April 8, 1981 at 4:30 PM. .Additional written statements and maps were received. FINDINGS: 1. Oil was first discovered in the Kuparuk area when Sinclair Oil Company tested oil from the Kuparuk River Formation at-their Ugnu No. 1 well in 1969. 2. Since 1969, more than 25 wells have been drilled and hundreds of miles of multi-fold seismic data have been acquired in an attempt to define the limits of the Kuparuk River oil accumulation. • • Conservation Order No. 173 Page 2 3. The area for the Prudhoe Ray Kuparuk River Oil Pool Rules was initially described on January 12, 1970 in Conservation Order No. 83-A and the area has not been changed since that date. 4. A fault, labeled the Eileen fault, exists in the western part of the Prudhoe Bay Field and the evidence indicates that this fault marks the western boundary of the oil accumulation defined as the Prudhoe Bay Kuparuk River Oil Pool. 5. There is doubt about the existence of the Eileen Fault north of the Prudhoe Bay Field and this area may have several faults. 6 . Some of the' a rca we s t and north r~ f the P rudhoc Bay Field should be included within the area where a common accumulation is possible and not covered by the Prudhoe Bay Kuparuk River Oil Pool rules. 7. The Kuparuk River Formation interval in the Atlantic Richfield Company West Sak River State #1 well appears adequate for defining the pool. 8. The area of oil accumulation appears to be controlled by structural dip and truncation to the south, trunca- tion of the formation to the west, northeast dip and possible faulting to the north and east, and a fault, the Eileen Fault, to the east. 9. The Kuparuk River formation consists of very fine to medium grained marine sandstone, usually occurring as three sand members separated by mudstones, siltstones and thinly bedded sandstones. 10. Sand members of the Kuparuk River Formation west of the Eileen Fault could be a common pool and share the same fluid c<,ntact. 11. To date, no wells have established the existence of a gas cap in the Kuparuk River Formation. 12. Although water has been found in the Kuparuk River Formation, no o~.l-water contacts have been substantiated in any individual sand members. 13 The aquifer underlying the Kuparuk River oil accumlation appears to be small in volume and the influx into the oil column is expected to be insignificant. 14. Preliminary development plans cover an area of 210 squares miles. Conservation Orde~No. 173 • Page 3 15. Initial reservoir pressure is estimated to average 3100 psia. with a bubble point pressure of 3000 psia. 16. Solution gas drive is expected to be the primary recovery mechanism. 17. All gas produced will be utilized, in accordance with 20 AAC 25.035 GAS UTILIZATION, for use as fuel, safety flaring, artificai lifting of oil, and injection into the reservoir for storage until a gas sales pipeline is available. 18. It is proposed that when gas sales facilities become available, the injected gas will be produced from the injected area for fuel and for sale.. 19. Waterflooding plans are being formulated for the reservoir. 20. The blowout prevention equipment and its use should be in accordance with 20 AAC 25.035 BLOWOUT PREVENTION EQUIPMENT. 21. The Kuparuk River Field, the name proposed by the operator for the area to be covered by these rules, is considered an appropriate name since it meets the - required criteria. 22. Development is planned under state-wide spacing regulations. 23. In the northern latitudes, the convergence of governmental survey lines toward true north results in some governmental quarter sections of less than 150 acres. 24. The drilling, completion and production from a well located in a governmental quarter section of no less than 125 acres will not adversely affect correlative rights. 25. Surface casing setting depths between 500 feet below the base of the permafrost and 2700 feet TVD will allow flexibility in the complex directional well programs. 26. Slotted liners, wire wrapped screen liners with and without gravel packing, and open hole completions may offer a means to reduce formation damage and improve oil recovery. 27. The casing design criteria being used has effectively eliminated casing collapse. Conservation Order No. 173 Page 4 28. Installation of downhole and surface automatic shut-in valves could prevent an uncontrolled flow of oil or gas. 29. A minimum subsurface safety valve setting depth of 500 feet should provide adequate protection from an uncon- trolled flow and should reduce the risk of damaging both the valve and the control line while running in the hole. 30. To properly regulate and operate the reservoir, performance must be carefully monitored and bottomhole pressure and gas-oil ratio test data must be obtained soon after production commences. 31. The contribution of each of the various perforated intervals in each producing well may be determined by running productivity profile surveys. NOW THEREFORE, IT IS ORDERED THAT Conservation Order No. 98-A is hereby amended by removing the following described area from the area covered by the Prudhoe Bay Kuparuk River Oil Pool Rules. _ T 11 N, x 10 E, U.M. Secs. 1,2,11,12,13,14,23, 24,25,26,35,and 36. T 12 N, R 10 E, U.M. Secs. 1,2,11,12,13,14,23, 24,25,26,35 and 36. T 11 N, R 11 E,U.M. Secs. 3,4,5,6,7,8,9,10, 11,14,15,16,17,18, 19,20,21,22,23,24,. 25,26,27,28,29,30, 31,32,33,34,35 and 36. T 13 N, R 10 E, U.M. Secs. 13,14,15,16,21,22, 23,24,25,26,27,28, 33,34,35 and 36. T 12 N, R 11 E, U.M. Secs. 3,4,5,6,7,8,18,19, 20,29,30,31,32 and 33. T 13 N, R 11 E, U.M. Secs. 17,18,19,20,28,29, 30, 31, 32 and 33. Conservation Order No. 173 Page 5 NOW THEREFORE IT IS FURTHER ORDERED THAT the rules hereinafter set forth apply to the following described area: T 9 N, R 6 E, U.M. Secs. 1,2,11,12,13 and 14. T 11 N, R 8 E, U.M. ALL T 9 N, R 7 E, U.M. Secs. 1,2,3,4,5,6,7,8,9, 10,11,12,13,14,15, 16,17 and 18. T 9 N, R 8 E, U.M Secs. 1,2,3,4,5,6,7,8,9, 10,11,12,13,14,15, 16,17 and 18. T 9 N, R 9 E, U.M. Secs. 1,2,3,4,5,6,7,8,9, 10,11,12,15,16,17 and 18. T 11 N, R 9 E, U.M. ALL T 11 N, R 10 E, U.M. ALL T 11 N, R 11 E, U.M. Secs. 3,4,5,6,7,8,9,10,11, 14,15,16,17,18,19,20, 21,22,23,24,25,26,27, 28,29,30,31,32,33,34, 35 and 36. T 12 N, R 7 E, U.M. Secs. 25,26,35 and 36. T 9 N, R 10 E, U,M. T 12 N, R 8 E, U.M. Secs. 1,2,3,4,5,6,7,8,9, ALL 10,11 and 12. T 12 N, R 9 E, U.M. T 10 N, R 6 E, U.M. ALL Secs. 1,2,3,4,9,10,11,12,13, 14,15,16,21,22,23,24, T 12 N, R 10 E, U.M. 25,26,35 and 36. ALL T 10 N, R 7 E, U.M. T 12 N, R 11 E, U.M. ALL Secs. 3,4,5,6,7,8,18,19,20, 29,30,31,32 and 33. T 10 N, R 8 E, U.M. ALL T 10 N, R 9 E, U.M. T 13 N, R 8 E, U.M. ALL Secs,.. 13,14,23,24,25,26, 27,28,33,34,35 and T 10 N, R 10 E, U.M. 36. ALL T 13 N, R 9 E, U.M. T 10 N, R 11 E, U.M. ALL Secs. 5,6,7,8,17,18,19 and 20, T 13 N, R 10 E, U.M. ALL T 11 N, R 6 E, U.M. Secs. 25,26,35 and 36. T 13 N, R 11 E, U.M. Secs. 7,8,16,17,18,19,20,21, T 11 N, R 7 E, U.M. 28,29,30,31,32 and 33. -Secs. 1,2,3,4,9,10,11,12, 13,14,15,16,17,18,19, 20.,21,22,23,24,25,26, _. 27,28,29,30,31,32,33, 34,35 and 36. Conservation Orcer ~• 173 • Page 6 Rule 1. Name of Field The name of the field shall be the Kuparuk River Field. Rule 2. Definition_ of Pool The name of the Pool in the Kuparuk River Field shall be the Kuparuk River Oil Pool and is defined as the accumulation of oil that is common to and correlates with the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 well be tween the depths of 6,474 and 6,880 feet. Rule 3. Well Spacing ~,, C,~, i $ ~ ~ e.c7_~q`~~ C •~', ^oj Not more than one well may be drilled on any governmental quarter section or governmental lot corresponding to it nor may any well be drilled on a governmental quarter section or governmental lot corresponding to it which contains less than 125 acres, nor may the Pool be opened in a well bore that is closer than 500 feet to any property line nor closer than 1,000 feet to the Pool opened to the well bore in another well. Rule 4 Casing and Cementing Requirements (a) Casing and cementing requirements are as specified in 20 AAC 25.03G. CASING AND CEMENTING. except as modified below. {b) For proper anchorage and to prevent an uncontrolled flow, a conductor casing shall be set at Ieast 75 feet below the surface and sufficient cement shall be used to fill the annulus behind the pipe to the surface. (c) For proper anchorage, to prevent an uncontrolled flow, and to protect the well from the effects of permafrost thaw-subsidence and freeze back, a string of surface casing shall be set at least 500 measured feet below the base of the perma- frost section but not below 2700 feet true vertical depth. Sufficient cement shall be used to fill the annulus behind the casing to the surface. (d) The surface casing, including connections, shall have minimum post-yield strain properties of 0.9o in tension and 1.26 in compression. (1) The only types and grades of casing, with threaded connections, trat have been shown to meet the requirements in (d) above and have been approved for use as surface casing are the following: (A) 13-3/8 inch, 72 pounds/foot, L-80, Buttress; (B) 13-3/8 inch, 72 pounds/foot, N-80, Buttress; (C) 10-3/4 inch, 45.5 pounds/foot, K-55, Buttress; • • Conservation Order No. 173 Page 7 (2) The Commission may approve other types and grades of surface casing upon a showing that the proposed casing and connection can meet the post-yield strain require- ments in (d) above. This evidence shall consist of one of. the following: (A) full scale tensile and compressive tests; (B) finite element model studies; or, (C) other types of axial strain data accep- table to the Commission. (e) Other means for maintaining the integrity of the well from the effects of permafrost thaw-subsidence and freeze back may be approved by the Commission upon application. (f) The Commission may approve alternative completion methods (to 20 AAC 25.030 (b) (4) and (5)) upon application and presentation of data which shows the alternatives are based on accepted engineering principles. Such alternative designs may include: (1) slotted liners, wire wrapped screen liners, or combinations thereof, landed inside of open hole and may be gravel packed; (2) open hole completions provided that the casing is set not more than 200 feet above the productive zone. Rule 5. Automatic Shut-In Equipment (a) Upon completion, each well which unassisted flow of hydrocarbons must be equipper Sion-approved ~(1) fail-safe automatic surface (SSV) capable of preventing an uncontrolled ically closing if such a flow should occur; is capable of 3 with a commis- safety valve flow by automat- and (2) fail-safe automatic surface controlled subsurface safety valve (SSSV), unless another type of subsur- face valve is approved by the Commission; this valve must be in the tubing string located at a depth of 500 feet or greater below ground level; the valve must be capable of preventing an uncontrolled flow by automatically closing if such a flow should occur. (b) A representative of the Commission will witness operation and performance tests at intervals and times as pre- scribed by the Commission to confirm that the SSV, SSSV, and alI associated equipment are in proper working condition; and # • Conservation Order No. 173 Page 8 (c) A well that is not capable of unassisted flow of hvc?rocarbons as determined by a "no flow" performance test wit- nessed by a commission representative is not required to have fail-safe automatic SSV or SSSV valves. Rule 6. Safety Flares (a) The daily average volume of 250 MCF/day is permitted for a safety flare in the Central Production Facility operated by Atlantic Richfield Company. (b) Safety flare volumes for additional facilities may be approved administratively upon application. (c) Safety flare volumes may be increased or decreased administratively. Rule 7. Gas-Oil Ratio Tests Between 90 and 120 days after continuous production and each six months thereafter a gas-oil ratio test shall be taken on each producing well. The test shall be of at least 12 hours duration and shall be conducted at the normal producing rate of the well. Test results shall be reported on Gas-Oil Ratio Test, Form 10-409. All tests run in a calendar month shall be reported by the 15th of the following month. Rule 8. Pressure Surveys „~,,_,_ ~,( c ..~......a..~T.Y•~ ~~ C. ~ , cZ~ O~ 27 (a) A static bottomhole pressure survey shall be taken on each well prior to initial sustained production. (b) Following initial sustained production from each governmental section, a transient pressure survey shall be taken on one well in the section after six months and after 18 months. (c) One of the wells from (b) above on each lease will be designated a key well and a transient pressure survey on this well shall be taken after 30 months production and annually thereafter. (d) Bottomhole pressures obtained by a static buildup pressur~:~ survey, a 24 hour shut-in instantaneous test or a multi- ple flow rate test will be acceptable. (e) Data from the surveys required in this rule shall be filed with the Commission by the last day of the. month follow- ing the month in which each survey is taken. Reservoir Pressure Report, Form 10-412 shall be utilized for all surveys with attach- ments for ccmplete additi onal data. Data submitted shall include, but are not limited to, rate, pressure, time, depths, temperature, and other well conditions necessary for complete analysis of each survey being conducted. The Pool pressure datum plane shall be 6,200 feet subsea. s Conservation Order No. 173 Page 9 (f) Results and data from any special reservoir pressure monitoring techniques, tests, or surveys shall also be submitted as prescribed in (e) of this rule. (g) By administrative order, the Commission may require additional pressure surveys or modify the key wells designated in (c) of this rule. Rule 9. Productivity Profiles (a) During the first year of production, a production survey shall be run in each well which has multiple sand intervals ope n to the well bore. (b) Subsequent surveys shall be run in wells which exhibit rapid changes in gas-oil ratio, water-oil ratio, or pro- ductivity. Subsequent surveys shall also be required in wells which have had remedial work performed to change the production profile unless the remedial work results in only one sand inter- val being open to the well bore. (c) Complete production survey data and results shall be recorded and filed with the Commission by the 15th day of the month following the month in which each survey is .taken. (d) By administrative order, the Commission shall spe cify additional surveys should it be determined that the surveys submitted under (a) and (b) are inadequate. Done at Anchorage, Alaska and dated May 6, 1981. ~~A ort,~d ~~ ~ ~. ti., :;~ BLS ~....w ~~. `~ltig rfox cor cyl H. anvil on, Chairman Alas a Oil and Gas Conservation Commission ~~4 ~ ~ ~ Harry W. Kugler, Commissioner Alaska Oil and Gas Conservation Commission ~-^ _ ,~~~ Lo .ie C. Sm' ,'`Commissioner Alaska Oil and Gas Conservation Commission