Regulations last checked for updates: Nov 22, 2024
Title 30 - Mineral Resources last revised: Nov 19, 2024
§ 550.1153 - When must I conduct a static bottomhole pressure survey?
(a) You must conduct a static bottomhole pressure survey under the following conditions:
| If you have . . .
| Then you must conduct . . .
|
|---|
| (1) A new producing reservoir, | A static bottomhole pressure survey within 90 days after the date of first continuous production.
|
| (2) A reservoir with three or more producing completions, | Annual static bottomhole pressure surveys in a sufficient number of key wells to establish an average reservoir pressure. The Regional Supervisor may require that bottomhole pressure surveys be performed on specific wells. |
(b) Your bottomhole pressure survey must meet the following requirements:
(1) You must shut-in the well for a minimum period of 4 hours to ensure stabilized conditions; and
(2) The bottomhole pressure survey must consist of a pressure measurement at mid-perforation, and pressure measurements and gradient information for at least four gradient stops coming out of the hole.
(c) You must submit to the Regional Supervisor the results of all static bottomhole pressure surveys on Form BOEM-140, Bottomhole Pressure Survey Report, within 60 days after the date of the survey.
(d) The Regional Supervisor may grant a departure from the requirement to run a static bottomhole pressure survey. To request a departure, you must submit a justification, along with Form BOEM-0140, Bottomhole Pressure Survey Report, showing a calculated bottomhole pressure or any measured data.
[76 FR 64623, Oct. 18, 2011, as amended at 80 FR 57096, Sept. 22, 2015]
§ 550.1154 - How do I determine if my reservoir is sensitive?
(a) You must determine whether each reservoir is sensitive. You must classify the reservoir as sensitive if:
(1) Under initial conditions it is an oil reservoir with an associated gas cap;
(2) At any time there are near-critical fluids; or
(3) The reservoir is undergoing enhanced recovery.
(b) For the purposes of this subpart, near-critical fluids are:
(1) Those fluids that occur in high temperature, high-pressure reservoirs where it is not possible to define the liquid-gas contact; or
(2) Fluids in reservoirs that are near bubble point or dew point conditions.
(c) The Regional Supervisor may reclassify a reservoir when available information warrants reclassification.
(d) If available information indicates that a reservoir previously classified as non-sensitive is now sensitive, you must submit a request to the Regional Supervisor to reclassify the reservoir. You must include supporting information, as listed in the table in § 550.1167, with your request.
(e) If information indicates that a reservoir previously classified as sensitive is now non-sensitive, you may submit a request to the Regional Supervisor to reclassify the reservoir. You must include supporting information, as listed in the table in § 550.1167, with your request.
§ 550.1155 - What information must I submit for sensitive reservoirs?
You must submit to the Regional Supervisor an original and two copies of Form BOEM-0127; one of the copies must be a public information copy in accordance with §§ 550.186 and 550.197, and marked “Public Information.” You must also submit two copies of the supporting information, as listed in the table in § 550.1167. You must submit this information:
(a) Within 45 days after beginning production from the reservoir or discovering that it is sensitive;
(b) At least once during the calendar year, but you do not need to resubmit unrevised structure maps (§ 550.1167(a)(2)) or previously submitted well logs (§ 550.1167(c)(1));
(c) Within 45 days after you revise reservoir parameters; and
(d) Within 45 days after the Regional Supervisor classifies the reservoir as sensitive under § 550.1154(c).
§ 550.1165 - What must I do for enhanced recovery operations?
(a) [Reserved]
(b) Before initiating enhanced recovery operations, you must submit a proposed plan to the BSEE Regional Supervisor and receive approval for pressure maintenance, secondary or tertiary recovery, cycling, and similar recovery operations intended to increase the ultimate recovery of oil and gas from a reservoir. The proposed plan must include, for each project reservoir, a geologic and engineering overview, Form BOEM-0127 (submitted to BOEM) and supporting data as required in § 550.1167, 30 CFR 250.1167, and any additional information required by the BSEE Regional Supervisor.
(c) [Reserved]
§ 550.1166 - What additional reporting is required for developments in the Alaska OCS Region?
(a)-(b) [Reserved]
(c) Every time you are required to submit Form BOEM-0127 under § 550.1155, you must request an MER for each producing sensitive reservoir in the Alaska OCS Region, unless otherwise instructed by the Regional Supervisor.
§ 550.1167 - What information must I submit with forms and for approvals?
You must submit the supporting information listed in the following table with the form identified in column 1 and for the approval required under this subpart identified in column 2:
|
| SRI BOEM-0127
(2 copies)
| Reservoir reclassification
|
|---|
| (a) Maps: | |
|
| (1) Base map with surface, bottomhole, and completion locations with respect to the unit or lease line and the orientation of representative seismic lines or cross-sections | | |
| (2) Structure maps with penetration point and subsea depth for each well penetrating the reservoirs, highlighting subject wells; reservoir boundaries; and original and current fluid levels | √ | √
|
| (3) Net sand isopach with total net sand penetrated for each well, identified at the penetration point | *
| |
| (4) Net hydrocarbon isopach with net feet of pay for each well, identified at the penetration point | *
| |
| (b) Seismic data: | |
|
| (1) Representative seismic lines, including strike and dip lines that confirm the structure; indicate polarity | | |
| (2) Amplitude extraction of seismic horizon, if applicable | | √
|
| (c) Logs: | |
|
| (1) Well log sections with tops and bottoms of the reservoir(s) and proposed or existing perforations | √ | √
|
| (2) Structural cross-sections showing the subject well and nearby wells | | √
|
| (d) Engineering data: | |
|
| (1) Estimated recoverable reserves for each well completion in the reservoir; total recoverable reserves for each reservoir; method of calculation; reservoir parameters used in volumetric and decline curve analysis | √
| |
| (2) Well schematics showing current and proposed conditions |
| |
| (3) The drive mechanism of each reservoir | √ | √
|
| (4) Pressure data, by date, and whether they are estimated or measured | | √
|
| (5) Production data and decline curve analysis indicative of the reservoir performance | | √
|
| (6) Reservoir simulation with the reservoir parameters used, history matches, and prediction runs (include proposed development scenario) | | *
|
| (e) General information: | |
|
| (1) Detailed economic analysis | |
|
| (2) Reservoir name and whether or not it is competitive as defined under § 250.105 | √ | √
|
| (3) Operator name, lessee name(s), block, lease number, royalty rate, and unit number (if applicable) of all relevant leases | | |
| (4) Geologic overview of project | | √
|
| (5) Explanation of why the proposed completion scenario will maximize ultimate recovery | | |
| (6) List of all wells in subject reservoirs that have ever produced or been used for injection | | √
|
(f) Depending on the type of approval requested, you must submit the appropriate payment of the service fee(s) listed in § 550.125, according to the instructions in § 550.126.
source: 76 FR 64623, Oct. 18, 2011, unless otherwise noted.
cite as: 30 CFR 550.1165