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Bottomhole Pressure (BHP) Survey Reporting Procedures with Suggested Reporting Format

30 CFR 250.1104 requires that an operator conduct a static BHP survey for each new reservoir and annually for any reservoir with three or more producing completions. BHP surveys are documented on Form MMS-140, “Bottomhole Pressure Survey Report.” Submit one original and one copy.

The Minerals Management Service (MMS) developed this document to assist you in preparing BHP Survey reports and to make both of our jobs easier. Please contact us if you have any questions on either the use of this document or any of our functions. We will endeavor to answer your questions completely or put you in contact with the person who can. You may copy any portion or this entire document for your use.

Paperwork Reduction Act of 1995 Statement (PRA). The collection of information referred to in this document provides guidance on reporting information requirements in 30 CFR 250, subparts A and K, and various MMS forms. The Office of Management and Budget (OMB) has approved the information collection requirements in these regulations and on the referenced forms. The OMB control numbers are 1010-0114 (subpart A regulations and form MMS-1123), 1010-0041 (subpart K regulations and form MMS-140), 1010-0044 (form MMS-123), 1010-0045 (form MMS-124), 1010-0046 (form MMS-125), 1010-0039 (form MMS-126), and 1010-0018 (form MMS-127). This document does not impose additional information collection requirements subject to the PRA.

For each new reservoir, conduct a static BHP survey within 3 months after the date of first continuous production. A BHP survey consists of pressure and gradient information at the middle of the well's perforated interval along with pressure and gradient information obtained at stops coming out of the hole. For each producing reservoir with three or more producing completions, conduct BHP surveys on a sufficient number of key wells (i.e., wells located in different structural positions in the reservoir - for example, on the east flank, west flank, and middle of an anticlinal structure) to establish an average reservoir pressure.

1. Within 60 days after the date of the survey submit the results of all BHP surveys run, even if they are not required under the regulations.

2. We may require the Federal lease operator to test specific wells.

1. Field: As designated by MMS field naming committee and on Form MMS-125, "Well Summary Report", Item 8.

2. Lease: Lease number of the producing interval as approved by MMS on the Form MMS-125, Item 4, or Form MMS-124, "Sundry Notices and Reports On Wells", Item 4.

3. Well Completion No.: Appropriate MMS approved well completion number (i.e., A001, A001D, etc.) on Form MMS-125, Item 3, or Form MMS-124, Item 3.

4. Reservoir Name: As designated by lease operator. The reservoir name is also on Form MMS-125, Item 50, or Form MMS-127, "Request for Reservoir Maximum Efficient Rate" (MER). The reservoir name will be stored in MMS information systems in no more than 12 numerical and/or alphabetic characters including blank spaces. Do not use slash (/) designation in the reservoir name as MMS uses this to designate commingled reservoirs by MMS.

5. API No.: A fourteen-digit number (including completion code) as assigned or approved by MMS on Form MMS-123, "Application For Permit to Drill" (APD), in the approval section at the bottom of the form. This number is also on Form MMS-125, Item 2, and Form MMS-124, Item 2.

6. Date of Test: The year, month, and day on which the test commenced.

   NOTE: Within 60 days from the date of the survey submit the BHP to the Reservoir Analysis Unit according to 30 CFR 250.1104 (c).

7. Operator Name: Lease operator of record, or the lease owner designee (Designated Operator) as stated on Form MMS-1123, "Designation of Operator", and filed with MMS.

8. Shut-in Time: Number of hours the well was shut in prior to the test.

9. Bottomhole Temperature: Maximum temperature at maximum survey depth (oF).

10. KB Elevation: Elevation, in feet, from kelly bushing to sea level.

11. Shut-in Tubing Pressure: Shut-in wellhead tubing pressure of the well in a stabilized condition (psia).

12. Product: Type of fluid produced. Oil (O) or Gas (G)

13. Test Number: If more than one test performed in same well on same date.

14. Tubinghead Flange: Elevation, in feet, from sea level to the tubinghead flange.

15. Perforations: List perforated interval in measured depths as shown on Form MMS-125, Items 46 and 47, or Form MMS-124, Item 36.

16. Measured Depth: The apparent depth measured along the longitudinal axis of the borehole from a specified point.

    NOTE: More than one measured depth and corresponding pressure are required.

17. True Vertical Depth: The vertical distance measured along the axis of the borehole from the rig kelly bushing to the depth of maximum depth of the well (in feet).

18. Pressure: The measured pressure (psia) at a specific depth.

19. Pressure Gradient: The change in pressure (DELTA PRESSURE) divided by the change in depth (DELTA DEPTH) (lbs./ft.).

20. Company Contact: Company representative whom the MMS would contact for additional information.

21. Phone Number: Telephone number of the Company Contact.

22. Remarks: Any additional comments deemed pertinent to the acceptance of the BHP survey.