SPE Mid-Continent Section Luncheon - Wednesday, May 18, 2022

701 North Union Avenue,Tulsa OK 74127

18 May, 2022

Description

SPE Mid-Continent Section Luncheon Presentation Luncheon cost is $25.00 for Professionals, $10 for Retired /Unemployed/Graduate Students, and free for Undergraduate Students. Buy or reserve your tickets here. Payment by credit card is for advanced registrations ONLY, no credit cards will be accepted at the meeting, only check or cash accepted at the door with a reservation. Registration ends Friday, May 13 at Noon. No walk-ins please. Wednesday, May 18, 2022 — 11:20 a.m.-1:00 p.m. Location: Tulsa Country Club, 701 North Union Avenue, Tulsa, OK 74127 Speaker: Jim Hacksma, Artificial Lift Consultant Topic: "Single-Point High-Pressure Gas-Lift" Description: “Single-Point High-Pressure Gas-Lift” (SPHPGL) as a new artificial lift method ● Tubing hangs free in casing (no gas-lift valves & no packer) ● Suitable for oil or gas wells + Suitable for virtually any rate (very high to very low) - Lift annulus at higher liquid rates + Lift tubing at lower liquid rates - Never pull the well - Never kill the well - Never risk reservoir damage ● Use a “booster” compressor (±1000 psi suction to 5500 psi max discharge) - Not very big (only 145 HP) - Not very long (booster needed only a few months) - Using 5500 psi (max), SPHPGL can operate at 16,000’ (max), without valves ● Save $$$ (CAPEX & OPEX) - Some first use 1) ESP, then 2) conventional GL, then 3) beam pump (expensive) - Instead, use SPHPGL for entire life of well (much cheaper) ● Approximate operating ranges of SPHPGL (in 5½” at 10,000’) - 0 - 10,000 B/D flow rate - 250 - 5500 psi injection pressure - 0.025 - 0.45 psi/ft flowing gradient - 300 - 4200 psi FBHP - 300 - 5000 MCFD “total” gas (inj + prod) ● SPHPGL is unconventional, simple & effective - Ideal for unconventional wells Jack Hacksma Jim Hacksma is a consultant specializing in innovative artificial lift solutions. He began his career in 1967, with Shell, installing PL in oil wells (before it became common to install PL in gas wells). As the GOR increased, beam pumping was replaced with PL. Surprisingly, production usually increased when PL was installed. In one exceptional case, 200 BOPD was produced with PL. In his 1972 paper “Predicting Plunger Lift Performance” (Southwestern Petroleum Short Course), he was the first to merge PL hardware performance with the well performance (IPR curve). For the first time one could predict production increases obtained with PL. More recent papers on PL often reference this early paper. In the early 1970’s he became one of the first to begin installing PL in low-rate gas wells to control liquid loading (previously PL had been used mostly in oil wells). In 1997, while working for Kerr-McGee, Jim developed “continuous gas circulation” (CGC). CGC is an innovative means of controlling liquid loading in low-rate gas wells (SPE #37426). CGC utilizes a small compressor to circulate gas thru the wellbore at high velocity and carry out liquids (tubing hanging free, no GLVs, no packer, no outside source of gas). CGC offers a number of advantages over other methods of gas well deliquification, (such as PL, foam, velocity strings, beam pumping, etc.). He retired from Kerr-McGee in 2003. In 2019 Jim co-authored “Single Point High Pressure Gas Lift Replaces ESP in Permian Basin Pilot Test” (SPE #195180). SPHPGL offers many advantages over other methods (ESP, conventional GL & beam pumping) commonly used in unconventional wells. SPHPGL can produce at rates comparable to an ESP. But, as the well declines, there is no need to replace SPHPGL with conventional GL or beam pumping. SPHPGL can be used for the entire life of the well. (Note: In an apparent attempt to maintain their competitive advantage, most operators will not publish their SPHPGL results. Thus, the info available on SPHPGL is rather limited. And it is impossible to say with certainty how many operators are using SPHPGL in how many wells.)